UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K
(Mark One)
For the fiscal year ended December 31 , 2021
OR
For the transition period from to
Commission File Number 1-16417
(Exact name of registrant as specified in its charter)
| (State or other jurisdiction of incorporation or organization) | (I.R.S. Employer Identification No.) | |||||||
(Address of principal executive offices) (Zip Code)
Registrant’s telephone number, including area code (210) 918-2000
Securities registered pursuant to Section 12(b) of the Act:
| Title of each class | Trading Symbol(s) | Name of each exchange on which registered | ||||||||||||
Securities registered pursuant to 12(g) of the Act: None.
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes þ No o
Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. Yes o No þ
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes þ No o
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes þ No o
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act:
þ | Accelerated filer | ☐ | ||||||||||||||||||
| Non-accelerated filer | ☐ | Smaller reporting company | ||||||||||||||||||
| Emerging growth company | ||||||||||||||||||||
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. o
Indicate by check mark whether the registrant has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report. ☑
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No þ
The aggregate market value of the common units held by non-affiliates was approximately $1.8 billion based on the last sales price quoted as of June 30, 2021, the last business day of the registrant’s most recently completed second quarter.
The number of common units outstanding as of January 31, 2022 was 110,101,839 .
DOCUMENTS INCORPORATED BY REFERENCE:
Portions of the Proxy Statement for the registrant’s 2022 annual meeting of unitholders, expected to be filed within 120 days after the end of the fiscal year covered by this Form 10-K, are incorporated by reference into Part III to the extent described therein.
NUSTAR ENERGY L.P.
FORM 10-K
TABLE OF CONTENTS
| PART I | ||||||||
| Items 1., 2. & 7 | ||||||||
| Item 1A. | ||||||||
| Item 1B. | ||||||||
| Item 3. | ||||||||
| Item 4. | ||||||||
| PART II | ||||||||
| Item 5. | ||||||||
| Item 6. | ||||||||
| Item 7A. | ||||||||
| Item 8. | ||||||||
| Item 9. | ||||||||
| Item 9A. | ||||||||
| Item 9B. | ||||||||
| Item 9C. | ||||||||
| PART III | ||||||||
| Item 10. | ||||||||
| Item 11. | ||||||||
| Item 12. | ||||||||
| Item 13. | ||||||||
| Item 14. | ||||||||
| PART IV | ||||||||
| Item 15. | ||||||||
| Item 16. | ||||||||
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PART I
Unless otherwise indicated, the terms “NuStar Energy,” “the Partnership,” “we,” “our” and “us” are used in this report to refer to NuStar Energy L.P., to one or more of our consolidated subsidiaries or to all of them taken as a whole.
CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION AND OTHER DISCLAIMERS
In this Form 10-K, we make certain forward-looking statements, such as statements regarding our plans, strategies, objectives, expectations, estimates, predictions, projections, assumptions, intentions, resources and the future impact of the coronavirus, or COVID-19, the responses thereto, economic activity and the actions by oil-producing nations on our business. While these forward-looking statements, and any assumptions upon which they are based, are made in good faith and reflect our current judgment regarding the direction of our business, actual results will almost always vary, sometimes materially, from any estimates, predictions, projections, assumptions or other future performance suggested in this report. These forward-looking statements can generally be identified by the words “anticipates,” “believes,” “expects,” “plans,” “intends,” “estimates,” “forecasts,” “budgets,” “projects,” “will,” “could,” “should,” “may” and similar expressions. These statements reflect our current views with regard to future events and are subject to various risks, uncertainties and assumptions, which may cause actual results to differ materially. Please read Item 1A. “Risk Factors” for a discussion of certain of those risks, uncertainties and assumptions.
If one or more of these risks or uncertainties materialize, or if the underlying assumptions prove incorrect, our actual results may vary materially from those described in any forward-looking statement. Other unknown or unpredictable factors could also have material adverse effects on our future results. Readers are cautioned not to place undue reliance on this forward-looking information, which is as of the date of this Form 10-K. We do not intend to update these statements unless we are required by the securities laws to do so, and we undertake no obligation to publicly release the result of any revisions to any such forward-looking statements that may be made to reflect events or circumstances after the date of this report or to reflect the occurrence of unanticipated events.
This Form 10-K contains trade names, trademarks and service marks of others, which are the property of their respective owners. Solely for convenience, trademarks and trade names referred to in this Form 10-K appear without the ® or ™ symbols.
ITEMS 1., 2. and 7. BUSINESS, PROPERTIES AND MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
OVERVIEW
NuStar Energy L.P. (NuStar Energy) is a Delaware limited partnership. Our principal executive offices are located at 19003 IH-10 West, San Antonio, Texas 78257, and our telephone number is (210) 918-2000. Our business is managed under the direction of the board of directors of NuStar GP, LLC, the general partner of our general partner, Riverwalk Logistics, L.P., both of which are wholly owned subsidiaries of ours. Our limited partner interests consist of the following:
•common units (NYSE: NS);
•8.50% Series A fixed-to-floating rate cumulative redeemable perpetual preferred units (NYSE: NSprA);
•7.625% Series B fixed-to-floating rate cumulative redeemable perpetual preferred units (NYSE: NSprB);
•9.00% Series C fixed-to-floating rate cumulative redeemable perpetual preferred units (NYSE: NSprC); and
•Series D cumulative convertible preferred units.
We are primarily engaged in the transportation, terminalling and storage of petroleum products and renewable fuels and the transportation of anhydrous ammonia. We also market petroleum products. The term “throughput” as used in this document generally refers to barrels of crude oil, refined product or renewable fuels or tons of ammonia, as applicable, that pass through our pipelines, terminals or storage tanks.
We divide our operations into the following three reportable business segments: pipeline, storage and fuels marketing. As of December 31, 2021, our assets included 9,935 miles of pipeline and 64 terminal and storage facilities, which provide approximately 57 million barrels of storage capacity. We conduct our operations through our wholly owned subsidiaries, primarily NuStar Logistics, L.P. (NuStar Logistics) and NuStar Pipeline Operating Partnership L.P. (NuPOP). We generate revenue primarily from:
•tariffs for transportation through our pipelines;
•fees for the use of our terminal and storage facilities and related ancillary services; and
•sales of petroleum products.
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We are focused on:
•maintaining safe, reliable operations, continuing our strong safety and environmental stewardship, and controlling costs;
•improving our existing assets through strategic internal growth projects, including renewable fuel enhancements;
•continuing to self-fund our spending with internally generated cash flows; and
•reducing our leverage metrics to further strengthen our balance sheet.
The following factors affect our results of operations:
•economic factors and price volatility;
•industry factors, such as changes in the prices of petroleum products that affect demand or production, or regulatory changes that could increase costs or impose restrictions on operations;
•factors that affect our customers and the markets they serve, such as utilization rates and maintenance turnaround schedules of our refining company customers and drilling activity by our crude oil production customers;
•company-specific factors, such as facility integrity issues, maintenance requirements and outages that impact the throughput rates of our assets; and
•seasonal factors that affect the demand for products transported by and/or stored in our assets and the demand for products we sell.
Please read Item 1A. “Risk Factors” for additional discussion on how these factors could affect our operations.
The following map depicts our assets at December 31, 2021:
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RECENT DEVELOPMENTS
In 2021, we prioritized protecting our employees, maintaining safe, reliable operations, executing our capital projects and exercising fiscal discipline, as we continued to take steps to reduce our leverage metrics and further strengthen our balance sheet. Our recent steps in 2021 include the sale of our Eastern U.S. Terminal Operations, as described below, and the early repayment of our senior notes, which addressed our near-term debt maturity and improved our debt metrics. In 2021, we met our goal of funding all our expenses, distribution requirements and capital expenditures using internally generated cash flows as well as our promise to publish our inaugural Sustainability Report. In January 2022, we also extended the maturity of our $1.0 billion unsecured revolving credit agreement to April 27, 2025. By repaying our senior notes and extending our credit agreement, we now have no debt maturing until 2025.
Point Tupper Terminal Sale Agreement. On February 11, 2022, we entered into an agreement to sell the equity interests in our wholly owned subsidiaries that own our Point Tupper terminal facility to EverWind Fuels for $60.0 million. The terminal facility has a storage capacity of 7.8 million barrels and is included in the storage segment. We expect to complete the sale in the first half of 2022 and will utilize the sales proceeds to improve our debt metrics.
Debt Amendments and Repayments. On January 28, 2022, we amended and restated our $1.0 billion unsecured revolving credit agreement to extend the maturity to April 27, 2025, replace the LIBOR-based interest rate and modify other terms. Also on January 28, 2022, we amended our $100.0 million receivables financing agreement to extend the scheduled termination date to January 31, 2025, replace the LIBOR-based interest rate and modify other terms. On November 1, 2021, we repaid our $250.0 million of 4.75% senior notes due February 1, 2022 with proceeds from the Eastern U.S. Terminals Disposition, as defined below. We repaid our $300.0 million of 6.75% senior notes due February 1, 2021 at maturity with borrowings under our revolving credit agreement. Please see Note 12 of the Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplementary Data” for additional information.
Eastern U.S. Terminals Disposition. On October 8, 2021, we completed the sale of nine U.S. terminal and storage facilities, including all our North East Terminals and one terminal in Florida (the Eastern U.S. Terminal Operations) to Sunoco LP for $250.0 million in cash (the Eastern U.S. Terminals Disposition) and utilized the proceeds from the sale to reduce debt and improve our debt metrics. The terminals had an aggregate storage capacity of 14.8 million barrels and were included in the storage segment. We recorded a non-cash asset impairment loss of $95.7 million and a non-cash goodwill impairment loss of $34.1 million in the third quarter of 2021, which are reported in “Asset impairment losses” and “Goodwill impairment losses,” respectively, on the consolidated statement of income for the year ended December 31, 2021. Please refer to Note 4 of the Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplementary Data” for additional information.
Houston Pipeline Impairment. In the third quarter of 2021, we recorded a non-cash asset impairment charge of $59.2 million within our pipeline segment related to our refined product pipeline extending from Mt. Belvieu, Texas to Corpus Christi, Texas (the Houston Pipeline). Please refer to Note 4 of the Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplementary Data” for additional information.
COVID-19. The coronavirus, or COVID-19, had a severe negative impact on global economic activity in 2020, which significantly reduced global demand for petroleum products and increased the volatility of crude oil prices, beginning in March 2020. While a number of countries, including the United States, made significant progress during 2021 deploying COVID-19 vaccines, which has improved the economic conditions and outlook in those nations, many more continue to struggle to obtain and/or disseminate vaccinations to their populace, which continues to frustrate widespread global economic recovery. Even in the United States, if a sufficient proportion of people are not vaccinated, or as variants emerge, we may continue to face surges in COVID-19 cases in some regions, which could slow the pace of domestic economic improvement and undermine demand in the markets our assets serve. We continue to closely monitor each of our locations to ensure the safety of our employees as well as the operational functionality of each location.
Ongoing uncertainty surrounding the COVID-19 pandemic, including its duration and lingering impacts to the economy have caused and may continue to cause volatility and could have a significant impact on management’s estimates and assumptions in 2022 and beyond.
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TRENDS AND OUTLOOK
As America continues to recover from the impact of COVID-19 and returns to normal activity and growth, we continue to see signs of stabilization and improvement, across the U.S. and in NuStar’s footprint. U.S. refined product demand outlook has improved as COVID-19 vaccinations have continued to allow more people to return to normal day-to-day activities and to begin traveling. However, variants may emerge that could significantly increase COVID-19 case counts, which may further impact the overall demand recovery in 2022.
Refined product demand on NuStar’s pipeline systems rebounded in 2021 to pre-pandemic levels or higher. We expect our refined products pipeline systems to perform at or above 100% of our pre-pandemic levels for 2022. Steady recovery in refined product demand has increased U.S. refiners’ demand for crude oil, which has contributed to increased throughputs on certain of our crude oil pipelines. Rebounding crude demand in the U. S. and abroad, has, in turn, contributed to higher global crude prices, which has in turn improved demand for U.S. shale production, particularly in the Permian Basin. We believe the Permian Basin, and our system in particular, has geological advantages over other shale plays, including lower production costs and higher product quality, that have benefited and will continue to benefit our assets in 2022 as crude demand, price and production continue to recover. Sustained healthy U.S. shale production growth, when combined with improving global demand, drives U.S. export growth over time; however, global demand has yet to rebound to pre-pandemic levels, which impacts crude volumes on our Corpus Christi Crude System, as well as our St. James terminal. In addition, we continue to expect to benefit from the growth of our renewable fuels distribution system on the West Coast. We expect to provide an increasing share of California’s renewable fuels as we complete our planned tank conversion projects.
The COVID-19 pandemic continues to have lingering impacts that, when combined with other factors, can ripple through the U.S. economy, including rising inflation rates and supply chain issues that affected certain industries and geographic areas to varying degrees during 2021 and, may continue or worsen in 2022. For 2022 and in response to rising inflation, we expect interest rates to increase, which will increase the interest expense related to our variable rate debt; however, we also expect many of our pipelines to benefit from tariff rate increases. We plan to continue to manage our operations with fiscal discipline in this turbulent environment and remain committed to improving our debt metrics. We expect to continue to fund all of our expenses, distribution requirements and capital expenditures for the full-year 2022 using internally generated cash flows.
Our outlook for the partnership, both overall and for any of our segments, may change, as we base our expectations on our continuing evaluation of several factors, many of which are outside our control. These factors include, but are not limited to, uncertainty surrounding the COVID-19 pandemic, including its duration and lingering impacts to the economy; uncertainty surrounding future production decisions by the Organization of Petroleum Exporting Countries and other oil-producing nations (OPEC+); the state of the economy and the capital markets; changes to our customers’ refinery maintenance schedules and unplanned refinery downtime; crude oil prices; the supply of and demand for petroleum products, renewable fuels and anhydrous ammonia; demand for our transportation and storage services; the availability and costs of personnel, equipment, supplies and services essential to our operations; the ability to obtain timely permitting approvals; and changes in laws and regulations affecting our operations.
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CONSOLIDATED RESULTS OF OPERATIONS
The following discussion of our results of operations should be read in conjunction with Item 8. “Financial Statements and Supplementary Data” included in this report, which also contains additional detailed financial information about our segments in Note 24 of the Notes to Consolidated Financial Statements. A comparative discussion of our 2020 to 2019 results of operations can be found in Items 1., 2., and 7. “Business, Properties and Management’s Discussion and Analysis of Financial Condition and Results of Operations” included in our Annual Report on Form 10-K for the year ended December 31, 2020 filed with the Securities and Exchange Commission (SEC) on February 25, 2021.
The following table presents our consolidated financial results for the year ended December 31, 2021, compared to the year ended December 31, 2020:
| Year Ended December 31, | |||||||||||||||||
| 2021 | 2020 | Change | |||||||||||||||
| (Thousands of Dollars, Except Per Unit Data) | |||||||||||||||||
| Statement of Income Data: | |||||||||||||||||
| Revenues: | |||||||||||||||||
| Service revenues | $ | 1,157,410 | $ | 1,205,494 | $ | (48,084) | |||||||||||
| Product sales | 461,090 | 276,070 | 185,020 | ||||||||||||||
| Total revenues | 1,618,500 | 1,481,564 | 136,936 | ||||||||||||||
| Costs and expenses: | |||||||||||||||||
| Costs associated with service revenues | 654,666 | 680,055 | (25,389) | ||||||||||||||
| Cost associated with product sales | 417,413 | 256,066 | 161,347 | ||||||||||||||
| Asset impairment losses | 154,908 | — | 154,908 | ||||||||||||||
| Goodwill impairment losses | 34,060 | 225,000 | (190,940) | ||||||||||||||
| General and administrative expenses | 113,207 | 102,716 | 10,491 | ||||||||||||||
| Other depreciation and amortization expense | 7,792 | 8,625 | (833) | ||||||||||||||
| Total costs and expenses | 1,382,046 | 1,272,462 | 109,584 | ||||||||||||||
| Operating income | 236,454 | 209,102 | 27,352 | ||||||||||||||
| Interest expense, net | (213,985) | (229,054) | 15,069 | ||||||||||||||
| Loss on extinguishment of debt | — | (141,746) | 141,746 | ||||||||||||||
| Other income (expense), net | 19,644 | (34,622) | 54,266 | ||||||||||||||
| Income (loss) before income tax expense | 42,113 | (196,320) | 238,433 | ||||||||||||||
| Income tax expense | 3,888 | 2,663 | 1,225 | ||||||||||||||
| Net income (loss) | $ | 38,225 | $ | (198,983) | $ | 237,208 | |||||||||||
| Basic and diluted net loss per common unit: | $ | (0.99) | $ | (3.15) | $ | 2.16 | |||||||||||
Overview
We recorded net income of $38.2 million for the year ended December 31, 2021, which includes non-cash asset and goodwill impairment losses related to our Eastern U.S. Terminal Operations of $95.7 million and $34.1 million, respectively, and a non-cash asset impairment loss of $59.2 million on our Houston Pipeline, as well as a gain of $14.9 million for insurance recoveries related to the 2019 fire at our Selby terminal.
For the year ended December 31, 2020, the net loss of $199.0 million is mainly due to a non-cash goodwill impairment charge of $225.0 million in the first quarter of 2020 related to our crude oil pipelines reporting unit, a loss on extinguishment of debt of $141.7 million, primarily resulting from the early repayment of $500.0 million of borrowings outstanding under our $750.0 million unsecured term loan credit agreement in the third quarter of 2020, and a loss of $34.7 million on the sale of our Texas City terminals in December 2020 (the Texas City Sale).
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Operating income increased $27.4 million for the year ended December 31, 2021, compared to the year ended December 31, 2020, primarily due to higher operating income from our pipeline segment due to a rebound in demand across most of our pipelines in 2021. Partially offsetting the increase were the following: (i) the impacts of a winter storm in the first quarter of 2021; (ii) the continuing effects of the COVID-19 global pandemic; and (iii) lower operating income from our storage segment in 2021 due to the Eastern U.S. Terminals Disposition and the Texas City Sale and lower demand at certain terminal facilities.
Corporate Items
General and administrative expenses increased $10.5 million for the year ended December 31, 2021, compared to the year ended December 31, 2020, mainly due to higher compensation costs.
Interest expense, net decreased $15.1 million for the year ended December 31, 2021, compared to the year ended December 31, 2020, mainly due to lower overall debt balances following the repayment of outstanding debt with the proceeds from our October 2021 and December 2020 asset sales described above. In addition, interest expense was lower in 2021 due to the repayment of the $750.0 million unsecured term loan credit agreement in September 2020 and senior note repayments in 2021, which more than offset the interest expense from the September 2020 issuance of $1.2 billion of senior notes.
We recorded other income, net of $19.6 million for the year ended December 31, 2021, compared to other expense, net of $34.6 million for the year ended December 31, 2020, mainly due to a gain of $14.9 million for insurance recoveries in 2021 related to the 2019 Selby terminal fire and a non-cash loss of $34.7 million related to the Texas City Sale in 2020.
SEGMENTS AND RESULTS OF OPERATIONS
PIPELINE SEGMENT
Our pipeline operations consist of the transportation of refined products, crude oil and anhydrous ammonia. As of December 31, 2021, we owned and operated:
•refined product pipelines with an aggregate length of 3,205 miles and crude oil pipelines with an aggregate length of 2,230 miles in Texas, Oklahoma, Kansas, Colorado and New Mexico (collectively, the Central West System);
•a 2,050-mile refined product pipeline originating in southern Kansas and terminating at Jamestown, North Dakota, with a western extension to North Platte, Nebraska and an eastern extension into Iowa (the East Pipeline);
•a 450-mile refined product pipeline originating at Marathon Petroleum Corporation’s (Marathon) Mandan, North Dakota refinery and terminating in Minneapolis, Minnesota (the North Pipeline); and
•a 2,000-mile anhydrous ammonia pipeline originating in the Louisiana delta area and then running north through the Midwestern United States to Missouri before forking east and west to terminate in Indiana and Nebraska (the Ammonia Pipeline).
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The following table lists information about our pipeline assets:
As of December 31, 2021 | Throughput For the year ended December 31, | ||||||||||||||||||||||||||||
| Region / Pipeline System | Length | Terminals | Tank Capacity | 2021 | 2020 | ||||||||||||||||||||||||
| (Miles) | (Barrels) | (Barrels/Day) | |||||||||||||||||||||||||||
| Central West System: | |||||||||||||||||||||||||||||
| McKee Refined Product System | 2,276 | — | — | 167,029 | 146,379 | ||||||||||||||||||||||||
| Three Rivers System | 373 | — | — | 106,526 | 94,892 | ||||||||||||||||||||||||
| Valley Pipeline System | 271 | — | 55,790 | 52,513 | |||||||||||||||||||||||||
| Other | 285 | — | — | 18,362 | 7,600 | ||||||||||||||||||||||||
| Central West Refined Products Pipelines | 3,205 | — | — | 347,707 | 301,384 | ||||||||||||||||||||||||
| Corpus Christi Crude Pipeline System | 538 | 8 | 2,157,000 | 423,528 | 439,852 | ||||||||||||||||||||||||
| McKee Crude System | 598 | — | 1,039,000 | 146,248 | 126,323 | ||||||||||||||||||||||||
| Ardmore System | 119 | — | 824,000 | 81,609 | 81,569 | ||||||||||||||||||||||||
| Permian Crude System | 975 | 3 | 1,583,000 | 630,183 | 590,013 | ||||||||||||||||||||||||
| Central West Crude Oil Pipelines | 2,230 | 11 | 5,603,000 | 1,281,568 | 1,237,757 | ||||||||||||||||||||||||
| Total Central West System | 5,435 | 11 | 5,603,000 | 1,629,275 | 1,539,141 | ||||||||||||||||||||||||
| Central East System: | |||||||||||||||||||||||||||||
| East Pipeline | 2,050 | 18 | 5,905,000 | 155,610 | 146,397 | ||||||||||||||||||||||||
| North Pipeline | 450 | 4 | 1,502,000 | 50,365 | 47,128 | ||||||||||||||||||||||||
| Ammonia Pipeline | 2,000 | — | — | 31,507 | 29,933 | ||||||||||||||||||||||||
| Total Central East System | 4,500 | 22 | 7,407,000 | 237,482 | 223,458 | ||||||||||||||||||||||||
| Total | 9,935 | 33 | 13,010,000 | 1,866,757 | 1,762,599 | ||||||||||||||||||||||||
Description of Pipelines
Central West System. The Central West System covers a total of 5,435 miles, including refined product and crude oil pipelines. The refined product pipelines have an aggregate length of 3,205 miles (Central West Refined Products Pipelines) and transport gasoline, distillates (including diesel and jet fuel), renewable fuels, natural gas liquids and other products produced at the refineries to which they are connected, including Valero Energy Corporation’s (Valero Energy) McKee, Corpus Christi and Three Rivers refineries.
The crude oil pipelines have an aggregate length of 2,230 miles (Central West Crude Oil Pipelines) and transport crude oil and other feedstocks to the refineries to which they are connected, including Valero Energy’s McKee, Three Rivers and Ardmore refineries, or from the Permian Basin and Eagle Ford Shale regions to our North Beach marine export terminal or to third-party refineries in Corpus Christi, Texas. Our Corpus Christi Crude Pipeline System is comprised of pipelines that transport crude oil from the Eagle Ford region to Corpus Christi, Texas, including eight terminals along those pipelines, with aggregate storage capacity of 2.2 million barrels. In addition, the Corpus Christi Crude Pipeline System is connected to third-party long-haul pipelines that transport crude oil from the Permian Basin region to Corpus Christi, Texas.
Our Permian Crude System consists of crude oil transportation, pipeline connection and storage assets located in the Midland Basin of West Texas, that aggregate receipts from wellhead connection lines into intra-basin trunk lines for delivery to regional hubs and to connections with third-party mainline takeaway pipelines. The system consists of 975 miles of pipelines and covers approximately 500,000 dedicated acres controlled by producers, with approximately 320 receipt points. The Permian Crude System also includes three terminals in Texas, at Big Spring, Stanton and Colorado City, as well as several truck stations and other operational storage facilities, with an aggregate storage capacity of 1.6 million barrels.
Central East System. The Central East System covers a total of 4,500 miles and consists of the East Pipeline, the North Pipeline and the Ammonia Pipeline.
The East Pipeline covers 2,050 miles and transports refined products and natural gas liquids north via pipelines to our terminals and third-party terminals along the system and to receiving pipeline connections in Kansas. Shippers on the East Pipeline obtain
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refined products from refineries in Kansas, Oklahoma and Texas. The East Pipeline includes 18 truck-loading terminals, with storage capacity of 4.5 million barrels and two tank farms with storage capacity of 1.4 million barrels at McPherson and El Dorado, Kansas.
The North Pipeline originates at Marathon’s Mandan, North Dakota refinery and runs from west-to-east for approximately 450 miles to its termination in Minneapolis, Minnesota. The North Pipeline includes four truck-loading terminals with storage capacity of 1.5 million barrels.
The 2,000-mile Ammonia Pipeline originates in the Louisiana delta area, where it connects to three third-party marine terminals and three anhydrous ammonia plants located along the Mississippi River. The line then runs north through Louisiana and Arkansas into Missouri, where, at Hermann, Missouri, it splits into two branches, one of which goes east into Illinois and Indiana, while the other branch continues north into Iowa and then turns west into Nebraska. The Ammonia Pipeline is connected to multiple third-party-owned terminals, which include industrial facility delivery locations. Product is supplied to the pipeline from anhydrous ammonia plants in Louisiana and imported product delivered through the marine terminals. Anhydrous ammonia is primarily used as agricultural fertilizer. It is also used as a feedstock to produce other nitrogen derivative fertilizers and explosives.
Pipeline Operations
We charge tariffs on a per-barrel basis for transporting refined products, crude oil and other feedstocks in our refined product and crude oil pipelines and on a per-ton basis for transporting anhydrous ammonia in the Ammonia Pipeline. Fees related to storage facilities included with these pipeline systems predominately relate to the volumes transported on the pipelines and are included in the respective pipeline tariff. As a result, these storage facilities are included in this segment instead of the storage segment.
In general, shippers on our crude oil and refined product pipelines deliver petroleum products to our pipelines for transport to/from: (i) refineries that connect to our pipelines, (ii) third-party pipelines or terminals and (iii) our terminals for further delivery to marine vessels or pipelines. We charge our shippers tariff rates based on transportation from the origination point on the pipeline to the point of delivery.
Our pipelines are regulated by one or more of the following federal governmental agencies: the Federal Energy Regulatory Commission (the FERC), the Surface Transportation Board (the STB), the Department of Transportation (the DOT), the Environmental Protection Agency (the EPA) and the Department of Homeland Security. In addition, our pipelines are subject to the respective jurisdictions of the states those lines traverse. See “Rate Regulation” and “Environmental, Health, Safety and Security Regulation” below for additional discussion.
The majority of our pipelines are deemed to be “common carrier” lines. Common carrier activities are those for which transportation is available to any shipper who requests such services and satisfies the conditions and specifications for transportation. Published tariffs for our petroleum product pipeline shipments are (i) filed with the FERC for interstate pipeline shipments and (ii) filed with the relevant state authority for intrastate pipeline shipments.
We operate our pipelines remotely through an operational technology system called the Supervisory Control and Data Acquisition, or SCADA, system.
Demand for and Sources of Refined Products and Crude Oil
Throughput activity on our Central West Refined Product Pipelines and the East and North Pipelines depends on the level of demand for refined products and other products in the markets served by those pipelines, as well as the ability and willingness of the refiners and marketers with access to the pipelines to supply that demand through our pipelines. Demand for renewable products handled by our pipeline systems, such as biodiesel and ethanol, is driven by the overall level of demand for refined products mentioned above, as well as regulatory requirements and our customers’ goals to increase their use of renewable fuels.
The majority of the refined products delivered through the Central West Refined Product Pipelines and the North Pipeline are gasoline and diesel fuel that originate at refineries connected to our pipelines. Demand for motor fuels fluctuates as prices for these products fluctuate. Prices fluctuate for a variety of reasons, including the overall balance in supply and demand, which is affected by general economic conditions, among other factors. Prices for gasoline and diesel fuel usually increase in the warm weather months when people tend to drive automobiles more often and for longer distances.
Much of the refined products and natural gas liquids delivered through the East Pipeline, and a portion of volumes on the North Pipeline, are ultimately used as fuel for railroads, ethanol denaturant or in agricultural operations, including fuel for farm equipment, irrigation systems, trucks used for transporting crops and crop-drying facilities. Demand for refined products for agricultural use, and the relative mix of products required is affected by weather conditions in the markets served by the East and North Pipelines. The agricultural sector is also affected by government agricultural policies and crop commodity prices.
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Although periods of drought suppress agricultural demand for some refined products, particularly those used for fueling farm equipment, the demand for fuel to power irrigation systems often increases during such times. The mix of refined products delivered for agricultural use varies seasonally, with gasoline demand peaking in early summer, diesel fuel demand peaking in late summer and propane demand highest in the fall.
Our refined product pipelines are also dependent upon adequate levels of production of refined products by refineries connected to the pipelines, directly or through connecting pipelines. The refineries are, in turn, dependent upon adequate supplies of suitable grades of crude oil. Certain of our Central West Refined Products Pipelines are connected directly to Valero Energy refineries and are subject to long-term throughput agreements with Valero Energy. If operations at one of these refineries were discontinued or significantly reduced, it could have a material adverse effect on our operations, although we would endeavor to minimize the impact by seeking alternative customers for those pipelines.
The North Pipeline is heavily dependent on Marathon’s Mandan, North Dakota refinery, which primarily runs North Dakota crude oil (although it has the ability to process other crude oils), and an interruption in operations at the Marathon refinery could have a material adverse effect on our operations. In addition, the North Pipeline receives refined products from the Laurel, Montana refinery operated by CHS Inc. The majority of the refined products transported through the East Pipeline are produced at three refineries located at McPherson and El Dorado, Kansas and Ponca City, Oklahoma, which are operated by CHS Inc., HollyFrontier Corporation and Phillips 66, respectively. The East Pipeline also has access to Gulf Coast supplies of products through third-party connecting pipelines that receive products originating from Gulf Coast refineries.
Other than the Valero Energy refineries and the Marathon refinery described above, if operations at any one refinery were discontinued, we believe (assuming stable demand for refined products in markets served by the refined product pipelines) that the effects thereof would be short-term in nature, and our business would not be materially adversely affected over the long-term because such discontinued production could be replaced by other refineries or other sources.
Our crude oil pipelines are dependent on our customers’ continued access to sufficient crude oil and sufficient demand for refined products for our customers to operate their refineries. The supply of crude oil production (domestic and foreign) could fluctuate with the price of crude oil. Changes in crude oil prices could also affect the exploration and production of shale plays, which could affect demand for crude oil pipelines serving those regions, such as our Corpus Christi Crude Pipeline System and Permian Crude System. During periods of sustained low prices, or uncertainty in regulatory changes that could increase costs or impose restrictions on operations, producers tend to reduce their capital spending and drilling activity and narrow their focus to assets in the most cost-advantaged regions.
In addition, certain of our crude oil pipelines, including the McKee System, are the primary source of crude oil for our customers’ refineries. Therefore, these “demand-pull” pipelines are less affected by changes in crude oil prices. For example, refiners can benefit from lower crude oil prices if they are able to take advantage of lower feedstock prices in areas with healthy regional demand; however, as refined product inventories increase, refiners typically reduce their production rate, which may reduce the degree to which they are able to benefit from low crude prices.
The impacts from COVID-19 and actions by OPEC+, including crude oil price volatility and reduced refinery production rates, drilling activity and overall consumer demand, negatively impacted demand for our crude and refined product pipelines primarily in 2020. Although demand in most of our pipelines returned to pre-pandemic levels or higher in 2021, the lingering impact on economic activity from the COVID-19 pandemic could continue to cause volatility in demand for the transportation in our pipelines.
Demand for and Sources of Anhydrous Ammonia
Our Ammonia Pipeline is currently the only major pipeline in the United States transporting anhydrous ammonia into the nation’s corn belt. The pipeline is connected to domestic production facilities and also has the capability to receive products from outside the United States directly into the system.
Throughputs on our Ammonia Pipeline depend on overall demand for nitrogen fertilizer use, the price of natural gas, which is the primary component of anhydrous ammonia, and the level of demand for direct application of anhydrous ammonia as a fertilizer for crop production (Direct Application). Demand for Direct Application is dependent on the weather, as Direct Application is not effective when soil is either too wet or too dry.
Corn producers have fertilizer alternatives to anhydrous ammonia, such as liquid or dry nitrogen fertilizers. Liquid and dry nitrogen fertilizers are both less sensitive to weather conditions during application but are generally more costly than anhydrous ammonia. In addition, anhydrous ammonia has the highest nitrogen content of any nitrogen-derivative fertilizer.
Demand for anhydrous ammonia has been insulated from the negative impacts from COVID-19 by continued strong agricultural demand and lower-density population centers in the Midwest.
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Customers
As discussed above, our customers include integrated oil companies, refining companies and others. Valero Energy, the largest customer of our pipeline segment, accounted for approximately 26% of the total segment revenues for the year ended December 31, 2021. No other single customer accounted for a significant portion of the total revenues of our pipeline segment.
Competition and Other Business Considerations
Because pipelines are generally the lowest-cost method for intermediate and long-haul movement of crude oil and refined products, our more significant competitors are common carrier and proprietary pipelines owned and operated by major integrated and large independent oil companies and other pipeline companies in our service areas. Competition between common carrier pipelines is based primarily on transportation charges, quality of customer service and proximity to end users. Trucks may deliver products competitively for short-hauls; however, trucking costs render that mode of transportation uncompetitive with pipeline options for longer hauls or larger volumes.
Most of our refined product pipelines and certain of our crude oil pipelines within the Central West System are physically integrated with, and principally serve, refineries owned by Valero Energy. As a result, we do not believe that we will face significant competition for transportation services provided to the Valero Energy refineries we serve.
Certain of our crude oil pipelines serve areas and/or refineries that are affected by domestic shale oil production in the Eagle Ford, Permian Basin and Granite Wash regions. Our pipelines also face competition from other crude oil pipelines and truck transportation in these regions. However, some of that exposure is mitigated through our long-term contracts and minimum volume commitments with creditworthy customers.
The East and North Pipelines compete with an independent common carrier pipeline system owned by Magellan Midstream Partners, L.P. (Magellan) that operates approximately 100 miles east of and parallel to the East Pipeline and in close proximity to the North Pipeline. Certain of the East Pipeline’s and the North Pipeline’s delivery terminals are in direct competition with Magellan’s terminals. Competition with Magellan is based primarily on transportation charges, quality of customer service and proximity to end users.
Competitors of the Ammonia Pipeline include Midwest production facilities, nitrogen fertilizer substitutes and barge, truck and railroad transportation under certain market conditions.
Looking forward, we have seen growing interest for utilization of ammonia as a source for renewable electricity generation to power fuel-cell vehicles. While future uses for lower emission-producing “blue” and “green” ammonia are still developing, we are partnering with existing and potential customers to develop these projects, which could increase demand for and utilization of our Ammonia Pipeline.
Results of Operations
The following table presents operating highlights for the pipeline segment:
| Year Ended December 31, | |||||||||||||||||
| 2021 | 2020 | Change | |||||||||||||||
| Pipeline Segment: | (Thousands of Dollars, Except Barrel Data) | ||||||||||||||||
| Crude oil pipelines throughput (barrels/day) | 1,281,568 | 1,237,757 | 43,811 | ||||||||||||||
| Refined products and ammonia pipelines throughput (barrels/day) | 585,189 | 524,842 | 60,347 | ||||||||||||||
| Total throughput (barrels/day) | 1,866,757 | 1,762,599 | 104,158 | ||||||||||||||
| Throughput and other revenues | $ | 762,238 | $ | 718,823 | $ | 43,415 | |||||||||||
| Operating expenses | 202,481 | 198,010 | 4,471 | ||||||||||||||
| Depreciation and amortization expense | 179,088 | 177,384 | 1,704 | ||||||||||||||
| Asset impairment loss | 59,197 | — | 59,197 | ||||||||||||||
| Goodwill impairment loss | — | 225,000 | (225,000) | ||||||||||||||
| Segment operating income | $ | 321,472 | $ | 118,429 | $ | 203,043 | |||||||||||
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Pipeline segment revenues increased $43.4 million and throughputs increased 104,158 barrels per day for the year ended December 31, 2021, compared to the year ended December 31, 2020. Although 2020 began with strong demand in the first quarter, prior to the pandemic, demand was severely reduced for the remainder of the year, resulting from COVID-19 restrictions, including stay-at-home orders and business closures. In comparison, the results for the first quarter of 2021 were negatively affected by Winter Storm Uri, which brought snow and damaging ice and caused widespread power outages in Texas and surrounding states in February 2021, as well as the lingering effects of COVID-19 restrictions. However, by the second quarter of 2021, demand had largely recovered to pre-pandemic levels. Revenues and throughputs increased primarily due to the 2021 rebound in demand resulting in:
•an increase in revenues of $29.9 million and an increase in throughputs of 40,170 barrels per day on our Permian Crude System, which included an increase of $17.5 million in sales of crude oil from surplus pipeline loss allowance;
•an increase in revenues of $4.7 million and an increase in throughputs of 3,277 barrels per day on our Valley Pipeline System, combined with higher minimum volume commitments that began in September 2020;
•an increase in revenues of $18.2 million and an increase in throughputs of 12,450 barrels per day on our East and North pipelines combined;
•an increase in revenues of $13.0 million and an increase in throughputs of 40,575 barrels per day on our McKee System pipelines, partially offset by the effects of Winter Storm Uri in the first quarter of 2021;
•an increase in revenues of $3.3 million and an increase in throughputs of 11,634 barrels per day on our Three Rivers System, combined with the reactivation of our refined products pipeline to transport diesel to our Nuevo Laredo terminal in Mexico, which was at full service at the end of the first quarter of 2020; and
•an increase in revenues of $3.1 million and an increase in throughputs of 1,574 barrels per day on our Ammonia Pipeline due to strong agricultural demand.
These increases were partially offset by:
•a decrease in revenues of $22.1 million and a decrease in throughputs of 16,324 barrels per day on our Corpus Christi Crude Pipeline System, mainly due to lower demand for exports in 2021, with the most significant impact in the first quarter of 2021, compared to the first quarter of 2020 pre-pandemic demand; and
•a decrease in revenues of $7.2 million despite throughputs remaining flat on our Ardmore System, primarily due to fewer barrels moved at higher average tariffs in 2021, compared to 2020 and the expiration of a customer contract at the end of the first quarter of 2021. Volumes were flat due to lower demand in 2020 and fewer barrels moved due to Winter Storm Uri.
Operating expenses increased $4.5 million for the year ended December 31, 2021, compared to the year ended December 31, 2020, primarily due to higher compensation expense of $6.9 million and an increase in insurance expense of $2.5 million due to higher premiums, partially offset by a decrease of $4.5 million in maintenance and regulatory expenses, mainly on our Ammonia Pipeline.
Depreciation and amortization expense increased $1.7 million for the year ended December 31, 2021, compared to the year ended December 31, 2020, mainly due to the completion of projects on our Permian Crude System and other completed projects.
In the third quarter of 2021, we recorded a non-cash asset impairment charge of $59.2 million related to the southern section of our Houston Pipeline. In the first quarter of 2020, the negative impact of the COVID-19 pandemic, combined with actions by OPEC+, led to a decline in our unit price and market capitalization in March 2020 and, as a result, we recorded a non-cash goodwill impairment charge of $225.0 million related to our crude oil pipelines reporting unit. Please refer to Notes 4 and 10 of the Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplementary Data” for further discussion.
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STORAGE SEGMENT
Our storage segment is comprised of our facilities that provide storage, handling and other services for refined products, crude oil, specialty chemicals, renewable fuels and other liquids. As of December 31, 2021, we owned and operated 29 terminal and storage facilities in the United States, one terminal in Nuevo Laredo, Mexico and one terminal located in Point Tupper, Canada, with an aggregate storage capacity of 44.2 million barrels. The following table sets forth information about our terminal and storage facilities as of December 31, 2021:
| Facility | Tank Capacity | |||||||
| (Barrels) | ||||||||
| Colorado Springs, CO | 327,000 | |||||||
| Denver, CO | 110,000 | |||||||
| Albuquerque, NM | 250,000 | |||||||
| Rosario, NM | 167,000 | |||||||
| Catoosa, OK | 359,000 | |||||||
| Abernathy, TX | 161,000 | |||||||
| Amarillo, TX | 269,000 | |||||||
| Corpus Christi, TX | 491,000 | |||||||
| Corpus Christi, TX (North Beach) | 3,962,000 | |||||||
| Edinburg, TX | 345,000 | |||||||
| El Paso, TX (a) | 415,000 | |||||||
| Harlingen, TX | 286,000 | |||||||
| Laredo, TX | 218,000 | |||||||
| San Antonio, TX (b) | 379,000 | |||||||
| Southlake, TX | 569,000 | |||||||
| Nuevo Laredo, Mexico | 268,000 | |||||||
| Central West Terminals | 8,576,000 | |||||||
| St. James, LA | 9,906,000 | |||||||
| Houston, TX | 87,000 | |||||||
| Gulf Coast Terminals | 9,993,000 | |||||||
| Los Angeles, CA | 606,000 | |||||||
| Pittsburg, CA | 398,000 | |||||||
| Selby, CA | 2,672,000 | |||||||
| Stockton, CA | 817,000 | |||||||
| Portland, OR | 1,348,000 | |||||||
| Tacoma, WA | 391,000 | |||||||
| Vancouver, WA (b) | 774,000 | |||||||
| West Coast Terminals | 7,006,000 | |||||||
| Benicia, CA | 3,683,000 | |||||||
| Corpus Christi, TX | 4,030,000 | |||||||
| Texas City, TX | 3,141,000 | |||||||
| Refinery Storage Tanks | 10,854,000 | |||||||
| Point Tupper, Canada | 7,778,000 | |||||||
| Total | 44,207,000 | |||||||
(a)We own a 67% undivided interest in the El Paso refined product terminal. The tank capacity represents the proportionate share of capacity attributable to our ownership interest.
(b)Location includes two terminal facilities.
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Description of Major Terminal and Storage Facilities
Refinery Storage Tanks. We own and operate crude oil storage tanks with an aggregate storage capacity of 10.9 million barrels that are physically integrated with and serve refineries owned by Valero Energy at Corpus Christi and Texas City, Texas and Benicia, California. We lease our refinery storage tanks to Valero Energy in exchange for a fixed fee.
St. James, Louisiana. Our St. James terminal, which is located on the Mississippi River near St. James, Louisiana, has a total storage capacity of 9.9 million barrels. The facility is located on almost 900 acres of land, some of which is undeveloped. The majority of the storage tanks and infrastructure are suited for light to medium crude oil, with certain of the tanks capable of fuel oil or heated crude oil storage. Additionally, the facility has one barge dock and two ship docks and we can accommodate exports up to Aframax-class vessels. Our St. James terminal is connected to (i) offshore pipelines in the Gulf of Mexico, (ii) long-haul pipelines that can receive crude oil from the Eagle Ford, Permian Basin, other domestic shale plays and Canada, and (iii) pipelines connecting to refineries in the Gulf Coast. The St. James terminal also has two unit train rail facilities that are served by the Union Pacific Railroad. Each facility has the capacity to simultaneously off-load 120 railcars, at a minimum, in a 24-hour period.
Point Tupper. We own and operate a 7.8 million barrel terminalling and storage facility located at Point Tupper on the Strait of Canso, near Port Hawkesbury, Nova Scotia. This facility is the deepest ice-free marine terminal on the North American Atlantic coast, with access to the East Coast, Canada and the Midwestern United States markets via the St. Lawrence Seaway and the Great Lakes system. With one of the premier jetty facilities in North America, the Point Tupper facility can accommodate heavily laden ultra-large crude carriers (ULCCs) for loading and discharging crude oil, petroleum products and petrochemicals. Crude oil and petroleum product movements at the terminal are fully automated. Separate fees apply for use of the jetty facility, as well as associated services, including pilotage, tug assistance, line handling, launch service, emergency response services and other ship services (all of which are considered optional services). On February 11, 2022, we entered into an agreement to sell the equity interests in our wholly owned subsidiaries that own our Point Tupper facility and we expect to complete the sale in the first half of 2022.
Corpus Christi North Beach. We own and operate a 4.0 million barrel crude oil storage and terminalling facility located at the Port of Corpus Christi in Texas. The facility supports our pipelines that transport crude oil from the Eagle Ford and Permian Basin regions to Corpus Christi for export or refineries owned by third parties. This facility also provides our customers with the flexibility to segregate and deliver crude oil and processed condensate. This facility has access to four docks, including two private docks. We can accommodate Suezmax-class vessels and load crude oil onto ships simultaneously on all four docks.
We refer to our pipelines that transport crude oil from the Eagle Ford and Permian Basin regions to Corpus Christi, together with our Corpus Christi North Beach terminal, as the Corpus Christi Crude System.
Storage Operations
We generate storage segment revenues through fees for tank storage agreements, under which a customer agrees to pay for a certain amount of storage in a tank over a period of time (storage terminal revenues), and throughput agreements, under which a customer pays a fee per barrel for volumes moved through our terminals (throughput terminal revenues). Our terminals also provide blending, additive injections, handling and filtering services for which we charge additional fees. Certain of our facilities charge fees to provide marine services, such as pilotage, tug assistance, line handling, launch service, emergency response services and other ship services.
Demand for Storage Services
The operations of our refined product terminals depend in large part on the level of demand for products stored in our terminals in the markets served by those assets. Demand for our terminalling services will generally increase or decrease with demand for refined products, and demand for refined products tends to increase or decrease with the relative strength of the economy. In addition, the forward pricing curve can have an impact on demand. For example, crude oil traders focus less on the current market commodity price than on whether that price is higher or lower than expected future market prices: if the future price for a product is believed to be higher than the current market price, or a “contango market,” traders are more likely to purchase and store products to sell in the future at the higher price. On the other hand, when the current price of crude oil nears or exceeds the expected future market price, or “backwardation,” traders are no longer incentivized to purchase and store product for future sale. Our storage terminal revenues are somewhat insulated from demand volatility due to contracted rates for storage and minimum volume commitments.
Crude oil delivered to our St. James and Corpus Christi North Beach terminals will generally increase or decrease with crude oil production rates in western Canada and the Bakken, Permian and Eagle Ford shale plays. In addition, the market price relationship between various grades of crude oil impacts the demand for our unit train facilities at our St. James terminal.
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Prior to the COVID-19 pandemic, North American shale play production had increased exports of crude oil from Texas Gulf Coast ports, including our Corpus Christi North Beach facility, to destinations as close as the U.S. East Coast and as far away as Europe and Asia. Although the negative impact of COVID-19 has been partially mitigated by the low break-even point in the Permian and Eagle Ford shale plays, Corpus Christi exports have not returned to pre-pandemic levels due to lower global demand for refined products and crude oil.
Demand for renewable diesel, renewable jet fuel, ethanol and other renewable fuels continues to grow in markets served by our West Coast terminals due to new regulations with aggressive carbon emissions reduction goals. As this demand growth is expected to continue, we have completed, and continue to develop, renewable fuel storage projects at our West Coast terminals to meet this demand.
Overall, refinery production rates, drilling activity and overall consumer demand in the U.S. has rebounded in 2021 bringing demand for most of our terminal and storage facilities back to pre-pandemic levels. In addition, certain of our storage facilities continued to benefit in 2021 from the contango market that emerged in March and April of 2020 due to contracts that extended into 2021. However, the detrimental impact of the pandemic has continued to affect global demand, resulting in less crude oil exports from our Corpus Christi North Beach facility. The duration, severity and lingering impact on economic activity from the COVID-19 pandemic and future production decisions from OPEC+ could continue to cause volatility in demand for our terminal and storage facilities.
Customers
We provide storage and terminalling services for crude oil, refined products and other products to many of the world’s largest producers of crude oil, integrated oil companies, chemical companies, oil traders and refiners. In addition, our blending capabilities in our storage assets have attracted customers who have leased capacity primarily for blending purposes. Valero Energy and Trafigura Trading LLC, the largest customers of our storage segment, accounted for approximately 26% and 19%, respectively, of the total revenues of the segment for the year ended December 31, 2021. No other customer accounted for a significant portion of the total revenues of the storage segment.
Competition and Other Business Considerations
Many major energy and chemical companies own extensive terminal storage facilities. Although such terminals often have the same capabilities as terminals owned by independent operators, they generally do not provide terminalling services to third parties. In many instances, even major energy and chemical companies that have storage and terminalling facilities are also significant customers of independent terminal operators, especially terminals located in cost-effective locations near key transportation links, such as deep-water ports. Major energy and chemical companies also need independent terminal storage when their proprietary storage facilities are inadequate, due to size constraints, the nature of the stored material or specialized handling requirements.
Independent terminal owners generally compete on the basis of the location and versatility of terminals, service and price. A favorably located terminal will have access to various cost-effective transportation modes both to and from the terminal. Transportation modes typically include waterways, railroads, roadways and pipelines.
Terminal versatility is a function of the operator’s ability to offer complex handling requirements for diverse products. The services typically provided by the terminal include, among other things, the safe storage of the product at specified temperature, moisture and other conditions, as well as receipt at and delivery from the terminal, all of which must comply with applicable environmental regulations. A terminal operator’s ability to obtain attractive pricing is often dependent on the quality, versatility and reputation of the facilities owned by the operator. Operators with versatile storage capabilities typically require less modification prior to usage, ultimately making the storage cost to the customer more attractive. On the West Coast, regulatory priorities continue to increase demand for renewable fuels in the region, while at the same time, obtaining permits for such greenfield projects remains difficult, adding more value to our existing assets.
Our crude oil refinery storage tanks are physically integrated with and serve refineries owned by Valero Energy, and we have entered into various agreements with Valero Energy governing the use of these tanks. As a result, we believe that we will not face significant competition for our services provided to those refineries.
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Results of Operations
Eastern U.S. Terminal Operations. In the third quarter of 2021, we recorded non-cash asset and goodwill impairment losses of $95.7 million and $34.1 million, respectively, related to our Eastern U.S. Terminal Operations. The nine terminals had an aggregate storage capacity of 14.8 million barrels and were included in the storage segment until the sale closed on October 8, 2021.
Sale of Texas City Terminals. On December 7, 2020, we sold the equity interests in our wholly owned subsidiaries that owned two terminals in Texas City, Texas for $106.0 million. The two terminals had an aggregate storage capacity of 3.0 million barrels and were previously included in our storage segment.
Selby Terminal Fire. We recognized gains from business interruption insurance of $4.0 million and $6.7 million for the years ended December 31, 2021 and 2020, respectively, which are included in “Operating expenses” in the consolidated statements of income (loss) and relate to a fire in October 2019 at our terminal facility in Selby, California.
The following table presents operating highlights for the storage segment:
| Year Ended December 31, | |||||||||||||||||
| 2021 | 2020 | Change | |||||||||||||||
| Storage Segment: | (Thousands of Dollars, Except Barrel Data) | ||||||||||||||||
| Throughput (barrels/day) | 421,862 | 469,862 | (48,000) | ||||||||||||||
| Throughput terminal revenues | $ | 122,331 | $ | 136,632 | $ | (14,301) | |||||||||||
| Storage terminal revenues | 305,337 | 357,810 | (52,473) | ||||||||||||||
| Total revenues | 427,668 | 494,442 | (66,774) | ||||||||||||||
| Operating expenses | 185,597 | 205,569 | (19,972) | ||||||||||||||
| Depreciation and amortization expense | 87,500 | 99,092 | (11,592) | ||||||||||||||
| Asset impairment loss | 95,711 | — | 95,711 | ||||||||||||||
| Goodwill impairment loss | 34,060 | — | 34,060 | ||||||||||||||
| Segment operating income | $ | 24,800 | $ | 189,781 | $ | (164,981) | |||||||||||
Throughput terminal revenues decreased $14.3 million and throughputs decreased 48,000 barrels per day for the year ended December 31, 2021, compared to the year ended December 31, 2020, mainly due to a decrease in revenues of $18.7 million and a decrease in throughputs of 67,129 barrels per day at our Corpus Christi North Beach terminal. Consistent with lower volumes on our Corpus Christi Crude Pipeline System, these decreases at our Corpus Christi North Beach terminal were due to a decrease in export demand and volumes delivered to our customers’ refineries instead of over our docks in 2021, as well as a reduction in minimum volume commitments. These decreases were partially offset by an increase in revenues of $4.5 million and an increase in throughputs of 19,834 barrels per day at our Central West Terminals, due to the 2021 rebound in demand.
Storage terminal revenues decreased $52.5 million for the year ended December 31, 2021, compared to the year ended December 31, 2020, primarily due to:
•a decrease in revenues of $31.8 million due to the Texas City Sale in December 2020;
•a decrease in revenues of $16.5 million due to the Eastern U.S. Terminals Disposition in October 2021; and
•a decrease in revenues of $10.5 million and $5.0 million at our St. James and Point Tupper terminals, respectively, mainly due to the expiration of customer contracts.
These decreases were partially offset by the following:
•an increase in revenues of $5.7 million at our West Coast Terminals, mainly due to completed projects, resulting in new contracts and rate escalations, as well as higher throughputs and handling fees; and
•an increase in revenues of $1.7 million at our Central West Terminals, primarily due to the reactivation of our refined products pipeline to transport diesel to our Nuevo Laredo terminal in Mexico, which began full service at the end of the first quarter of 2020.
Operating expenses decreased $20.0 million for the year ended December 31, 2021, compared to the year ended December 31, 2020, primarily due to an aggregate decrease in operating expenses of $30.4 million due to the Eastern U.S. Terminals Disposition in October 2021 and the Texas City Sale in December 2020. This decrease was partially offset by an increase in compensation expense of $4.3 million, an increase in insurance expense of $3.5 million due to higher premiums and lower business interruption insurance recovery of $2.7 million in 2021 related to the Selby terminal.
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Depreciation and amortization expense decreased $11.6 million for the year ended December 31, 2021, compared to the year ended December 31, 2020, mainly due to lower depreciation and amortization expense related to the Eastern U.S. Terminals Disposition in October 2021 and the Texas City Sale in December 2020.
FUELS MARKETING SEGMENT
The fuels marketing segment includes our bunkering operations in the Gulf Coast, as well as certain of our blending operations associated with our Central East System. The results of operations for the fuels marketing segment depend largely on the margin between our costs and the sales prices of the products we market. Therefore, the results of operations for this segment are more sensitive to changes in commodity prices compared to the operations of the pipeline and storage segments. We enter into derivative contracts to attempt to mitigate the effects of commodity price fluctuations. The financial impacts of the derivative financial instruments associated with commodity price risk were not material for any periods presented. The COVID-19 pandemic has caused volatility in commodity prices and volumes in 2021 and 2020, especially for our blending operations and bunker fuel sales to cruise ships.
Customers for bunker fuel sales are mainly ship owners, including cruise line companies, marketers and traders. In the sale of bunker fuel, we compete with ports offering bunker fuels that are along the route of travel of the vessel. One of our customers, a marketer of petroleum products, was the largest customer of our fuels marketing segment and accounted for approximately 14% of the total segment revenues for the year ended December 31, 2021. No other customer accounted for a significant portion of the total revenues of the fuels marketing segment for the year ended December 31, 2021.
Results of Operations
The following table presents operating highlights for the fuels marketing segment:
| Year Ended December 31, | |||||||||||||||||
| 2021 | 2020 | Change | |||||||||||||||
| Fuels Marketing Segment: | (Thousands of Dollars) | ||||||||||||||||
| Product sales | $ | 428,608 | $ | 268,345 | $ | 160,263 | |||||||||||
| Cost of goods | 417,000 | 253,704 | 163,296 | ||||||||||||||
| Gross margin | 11,608 | 14,641 | (3,033) | ||||||||||||||
| Operating expenses | 427 | 2,408 | (1,981) | ||||||||||||||
| Segment operating income | $ | 11,181 | $ | 12,233 | $ | (1,052) | |||||||||||
Segment operating income decreased $1.1 million for the year ended December 31, 2021, compared to the year ended December 31, 2020, primarily due to lower gross margins of $4.8 million from our bunkering operations, partially offset by higher gross margins of $1.7 million from our blending operations and a credit loss recovery of $1.7 million that we received in the first quarter of 2021, which is included in operating expenses.
LIQUIDITY AND CAPITAL RESOURCES
OVERVIEW
Our primary cash requirements are for distributions to our partners, debt service, capital expenditures and operating expenses. Our partnership agreement requires that we distribute all “Available Cash” to our common limited partners each quarter. “Available Cash” is defined in the partnership agreement generally as cash on hand at the end of the quarter, plus certain permitted borrowings made subsequent to the end of the quarter, less cash reserves determined by our board of directors, subject to requirements for distributions for our preferred units. We may maintain our distribution level with other sources of Available Cash, as provided in our partnership agreement, including borrowings under our revolving credit agreement and proceeds from the sales of assets.
In prior years, our objective was to fund our reliability capital expenditures and distribution requirements with net cash provided by operating activities during that year. If we did not generate sufficient cash from operations to meet that objective, we used cash on hand or other sources of cash flow, such as borrowings under our revolving credit agreement, sales of non-strategic assets and funds raised through debt or equity offerings. Prior to 2021, we funded our strategic capital expenditures primarily from borrowings under our revolving credit agreement, funds raised through debt or equity offerings and/or sales of non-strategic assets. However, our ability to raise funds by issuing debt or equity depends on many factors beyond our control, including our ability to access such markets with the continued uncertainty surrounding the duration and severity of the impact from the COVID-19 pandemic. Our risk factors in Item 1A. “Risk Factors” describe the risks inherent to these sources of funding and the availability thereof.
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In 2020, due to the negative impacts of, and the continued uncertainty related to, the COVID-19 pandemic and actions taken by OPEC+, we took steps to preserve and enhance our liquidity, and we continued to prioritize liquidity in 2021 by extending the maturity on our $1.0 billion revolving credit agreement to April 27, 2025; extending the scheduled termination date on our $100.0 million receivables financing agreement to January 31, 2025; and selling our Eastern U.S. Terminal Operations on October 8, 2021. In 2021, we also reduced our strategic capital expenditures by over 10%, as compared to 2020, which had been lowered by approximately 50% to reduce our overall cash requirements at the beginning of the pandemic. We continue to manage our operations with fiscal discipline and monitor our cash requirements in this turbulent environment.
Beginning in 2021, in response to the shifting expectations of our industry, including continuing to reduce leverage, combined with the ongoing lack of access to equity markets and the COVID-19 environment, we positioned ourselves to fund all of our expenses, distribution requirements and capital expenditures using internally generated cash flows for the full-year. We met our objective in 2021, and we expect to do so again in 2022.
Beyond 2022, absent a change to the factors described above, including a return of access to equity capital markets, we plan to continue to fund our expenses, distribution requirements and capital expenditures with internally generated cash flows, which could include proceeds from asset dispositions. We have no long-term debt maturities until 2025, and we have been and expect to continue to be able to access debt capital markets to refinance those maturities. Our Series D Cumulative Convertible Preferred Units (Series D Preferred Units) become redeemable, at our option, beginning in 2023, which coincides with an increase in the distribution rate of those units. Beginning in 2028, the holders of the Series D Preferred Units have the option to require us to redeem their units, and we have begun taking steps to position ourselves to redeem the Series D Preferred Units gradually over the next several years in advance of the possible mandatory redemption. By reducing our leverage, primarily through the disposition of non-strategic assets in recent years, and continuing to increase the amount by which our internally generated cash flows exceed our expenses, distribution requirements and capital expenditures, we are increasing our financial flexibility. Beyond those items, we would also continue to evaluate other sources of liquidity to manage the optional or mandatory redemption of the Series D Preferred Units, including the issuance of common or other preferred units.
A discussion of our cash flows and other changes in financial position for 2019 can be found in Items 1., 2. and 7. “Business, Properties and Management’s Discussion and Analysis of Financial Condition and Results of Operations” included in our Annual Report on Form 10-K for the year ended December 31, 2020 filed with the SEC on February 25, 2021.
CASH FLOWS FOR THE YEARS ENDED DECEMBER 31, 2021 AND 2020
The following table summarizes our cash flows from operating, investing and financing activities (please refer to our Consolidated Statements of Cash Flows in Item 8. “Financial Statements and Supplementary Data”).
| Year Ended December 31, | |||||||||||
| 2021 | 2020 | ||||||||||
| (Thousands of Dollars) | |||||||||||
| Net cash provided by (used in): | |||||||||||
| Operating activities | $ | 501,478 | $ | 525,998 | |||||||
| Investing activities | 75,978 | (98,084) | |||||||||
| Financing activities | (725,579) | (291,384) | |||||||||
| Effect of foreign exchange rate changes on cash | 136 | 916 | |||||||||
| Net (decrease) increase in cash, cash equivalents and restricted cash | $ | (147,987) | $ | 137,446 | |||||||
For the years ended December 31, 2021 and 2020, net cash provided by operating activities exceeded our distributions to unitholders, reliability capital expenditures and strategic capital expenditures.
Net cash provided by operating activities decreased by $24.5 million for the year ended December 31, 2021, compared to the year ended December 31, 2020, primarily due to changes in working capital. Our working capital increased by $14.1 million for the year ended December 31, 2021, compared to a decrease of $11.9 million for the year ended December 31, 2020. Working capital requirements are mainly affected by our accounts receivable and accounts payable balances, which vary depending on the timing of payments. In addition, the timing of payments related to accrued interest payable changed due to the senior note repayments in 2021. Cash flows from operating activities include $19.1 million and $35.0 million of insurance proceeds for the years ended December 31, 2021 and 2020, respectively, related to repairs/cleanup costs and business interruption from the 2019 Selby terminal fire.
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For the year ended December 31, 2021, we recorded net cash provided by investing activities of $76.0 million, compared to net cash used in investing activities of $98.1 million for the year ended December 31, 2020, primarily due to higher proceeds from asset sales of $135.8 million.
Net cash used in financing activities increased by $434.2 million for the year ended December 31, 2021, compared to the year ended December 31, 2020, mainly due to an increase in net debt repayments. For the year ended December 31, 2021, we had net debt repayments of $412.7 million associated with senior note maturities, which we paid primarily with proceeds from asset sales. For the year ended December 31, 2020, we had $108.0 million in net borrowings and a $49.2 million payment to terminate interest rate swaps.
SOURCES OF LIQUIDITY
Issuance of 5.75% and 6.375% Senior Notes
On September 14, 2020, NuStar Logistics issued $600.0 million of 5.75% senior notes due October 1, 2025 and $600.0 million of 6.375% senior notes due October 1, 2030. We received proceeds of $1,182.0 million, net of issuance costs of $18.0 million, which we used to repay outstanding borrowings under the Term Loan, along with early repayment premiums (discussed further below), as well as outstanding borrowings under our Revolving Credit Agreement, as defined below. The interest on the 5.75% and 6.375% senior notes is payable semi-annually in arrears on April 1 and October 1 of each year, beginning on April 1, 2021. These notes rank equally with existing senior unsecured indebtedness and senior to existing subordinated indebtedness of NuStar Logistics. These notes contain terms comparable to our other senior notes and are guaranteed by NuStar Energy and NuPOP.
Revolving Credit Agreement
As of December 31, 2021, NuStar Logistics’ $1.0 billion unsecured revolving credit agreement (the Revolving Credit Agreement) had $884.8 million available for borrowing and $110.5 million of borrowings outstanding. Letters of credit issued under the Revolving Credit Agreement totaled $4.7 million as of December 31, 2021. Letters of credit limit the amount we can borrow under the Revolving Credit Agreement. Obligations under the Revolving Credit Agreement are guaranteed by NuStar Energy and NuPOP.
The Revolving Credit Agreement is subject to maximum consolidated debt coverage ratio and minimum consolidated interest coverage ratio requirements, which may limit the amount we can borrow to an amount less than the total amount available for borrowing. For the rolling period of four quarters ending December 31, 2021, the maximum allowed consolidated debt coverage ratio (as defined in the Revolving Credit Agreement) could not exceed 5.00-to-1.00 and the minimum consolidated interest coverage ratio (as defined in the Revolving Credit Agreement) must not be less than 1.75-to-1.00. The Revolving Credit Agreement also contains customary restrictive covenants, such as limitations on indebtedness, liens, mergers, asset transfers and certain investing activities. As of December 31, 2021, our consolidated interest coverage ratio was 2.11x and our consolidated debt coverage ratio was 3.99x.
On January 28, 2022, we amended and restated our unsecured Revolving Credit Agreement to, among other things: (i) extend the maturity date from October 27, 2023 to April 27, 2025; (ii) increase the maximum amount of letters of credit capable of being issued from $400.0 million to $500.0 million; (iii) replace LIBOR benchmark provisions with customary secured overnight financing rate, or SOFR, benchmark provisions; (iv) remove the 0.50x increase permitted in our consolidated debt coverage ratio for certain rolling periods in which an acquisition for aggregate net consideration of at least $50.0 million occurs; and (v) add baskets and exceptions to certain negative covenants.
In November 2021, S&P Global Ratings affirmed our credit rating and our rating outlook and, in October 2021, Fitch Ratings affirmed our credit rating and our rating outlook. In April 2021, Moody’s Investor Service Inc. affirmed our credit rating and changed our rating outlook from negative to stable. In August 2020, Moody’s Investor Service Inc. downgraded our credit rating from Ba2 to Ba3 and changed our rating outlook to negative. This rating downgrade caused the interest rate on our Revolving Credit Agreement to increase by 0.25% effective August 2020. The interest rate on the Revolving Credit Agreement and certain fees under the Receivables Financing Agreement, defined below, are the only debt arrangements that are subject to adjustment if our debt rating is downgraded (or upgraded) by certain credit rating agencies. The following table reflects the current ratings and outlook that have been assigned to our debt:
| Fitch Ratings | Moody’s Investor Service Inc. | S&P Global Ratings | |||||||||||||||
| Ratings | BB- | Ba3 | BB- | ||||||||||||||
| Outlook | Stable | Stable | Stable | ||||||||||||||
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Receivables Financing Agreement
NuStar Energy and NuStar Finance LLC (NuStar Finance), a special purpose entity and wholly owned subsidiary of NuStar Energy, are parties to a $100.0 million receivables financing agreement with a third-party lender (the Receivables Financing Agreement) and agreements with certain of NuStar Energy’s wholly owned subsidiaries (together with the Receivables Financing Agreement, the Securitization Program). The amount available for borrowing under the Receivables Financing Agreement is based on the availability of eligible receivables and other customary factors and conditions. The Securitization Program contains various customary affirmative and negative covenants and default, indemnification and termination provisions, and the Receivables Financing Agreement provides for acceleration of amounts owed upon the occurrence of certain specified events.
On January 28, 2022, the Receivables Financing Agreement was amended to, among other things: (i) extend the scheduled termination date from September 20, 2023 to January 31, 2025; (ii) reduce the floor rate in the calculation of our borrowing rates; and (iii) replace provisions related to the LIBOR rate of interest with references to SOFR rates of interest. Following the amendment, borrowings under the Receivables Financing Agreement bear interest, at NuStar Finance’s option, at a base rate or a SOFR rate, each as defined in the Receivables Financing Agreement.
Term Loan
On April 19, 2020, NuStar Energy and NuStar Logistics entered into an unsecured term loan credit agreement with certain lenders and Oaktree Fund Administration, LLC, as administrative agent for the lenders. The Term Loan provided for an aggregate commitment of up to $750.0 million pursuant to a three-year unsecured term loan credit facility. NuStar Logistics drew $500.0 million (the Initial Loan) on April 21, 2020 (the Initial Loan Funding Date). We utilized the proceeds from the Initial Loan, net of the original issue discount of $22.5 million (3.0% of the total commitment) and issuance costs of $14.4 million, to repay outstanding borrowings under our Revolving Credit Agreement.
On September 16, 2020, we used a portion of the net proceeds from the issuance of the 5.75% and 6.375% senior notes to repay the $500.0 million of outstanding borrowings under the Term Loan and pay related early repayment premiums totaling $97.6 million. We also recognized costs of $40.3 million related to unamortized debt issuance costs, unamortized discount and commitment fee, which resulted in a loss from extinguishment of debt of $137.9 million in the third quarter of 2020. We terminated the Term Loan on February 16, 2021.
Please refer to Note 12 of the Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplementary Data” for a discussion of our debt agreements.
Asset Sales
We used the proceeds from the Eastern U.S. Terminals Disposition in 2021 and the Texas City Sale in 2020 to reduce debt and thereby improve our debt metrics.
MATERIAL CASH REQUIREMENTS
Capital Expenditures
Our operations require significant investments to maintain, upgrade or enhance the operating capacity of our existing assets. Our capital expenditures consist of:
•strategic capital expenditures, such as those to expand or upgrade the operating capacity, increase efficiency or increase the earnings potential of existing assets, whether through construction or acquisition, as well as certain capital expenditures related to support functions; and
•reliability capital expenditures, such as those required to maintain the current operating capacity of existing assets or extend their useful lives, as well as those required to maintain equipment reliability and safety.
The following table summarizes our capital expenditures:
| Strategic Capital Expenditures | Reliability Capital Expenditures | Total | |||||||||||||||
| (Thousands of Dollars) | |||||||||||||||||
| For the year ended December 31: | |||||||||||||||||
| 2021 | $ | 140,867 | $ | 40,266 | $ | 181,133 | |||||||||||
| 2020 | $ | 159,507 | $ | 38,572 | $ | 198,079 | |||||||||||
Expected for the year ended December 31, 2022 | $ 130,000 - 160,000 | $ 35,000 - 45,000 | |||||||||||||||
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Strategic capital expenditures for the years ended December 31, 2021 and December 31, 2020 mainly consisted of expansion projects on our Permian Crude System and our West Coast biofuels terminal projects, and in 2020, expansion projects on our Corpus Christi Crude System. Strategic capital expenditures also included projects to increase flexibility at our St. James and other terminals in 2020. Reliability capital expenditures primarily related to maintenance upgrade projects at our terminals.
We expect our strategic capital expenditures for the year ended December 31, 2022 to include spending of approximately $55.0 million on expansion projects to accommodate production growth in the Permian Basin and approximately $25.0 million on projects to handle biofuels demand on the West Coast, as well as other smaller projects. We continue to evaluate our capital budget and internal growth projects can be accelerated or scaled back depending on market conditions or customer demand. Therefore, our actual capital expenditures for 2022 may increase or decrease from the expected amounts noted above. We expect to self-fund all of our capital expenditures in 2022.
Pension and Other Postretirement Plan Contributions
The NuStar pension plan was well-funded at December 31, 2021 and, accordingly, we did not make any discretionary contributions in 2021. During 2021, we contributed $0.3 million to our pension and postretirement benefit plans in order to fund current benefits. We will monitor our funding status in 2022 to determine if any contributions are required by regulations or laws, or, with respect to unfunded plans, necessary to fund current benefits. We expect to contribute approximately $9.9 million to our pension and postretirement benefit plans in 2022. Pension and postretirement benefit plans funding beyond 2022 is uncertain as the funding varies from year to year based upon changes in the fair value of the plan assets and actuarial assumptions.
Distributions
Common Limited Partners. Distribution payments are made to our common limited partners within 45 days after the end of each quarter as of a record date that is set after the end of each quarter. The following table summarizes information about cash distributions to our common limited partners applicable to the period in which the distributions were earned:
| Cash Distributions Per Unit | Total Cash Distributions | Record Date | Payment Date | |||||||||||||||||||||||
| (Thousands of Dollars) | ||||||||||||||||||||||||||
| Quarter ended: | ||||||||||||||||||||||||||
| December 31, 2021 | $ | 0.40 | $ | 44,008 | February 8, 2022 | February 14, 2022 | ||||||||||||||||||||
| September 30, 2021 | 0.40 | 43,814 | November 8, 2021 | November 12, 2021 | ||||||||||||||||||||||
| June 30, 2021 | 0.40 | 43,814 | August 6, 2021 | August 12, 2021 | ||||||||||||||||||||||
| March 31, 2021 | 0.40 | 43,834 | May 10, 2021 | May 14, 2021 | ||||||||||||||||||||||
Year ended December 31, 2021 | $ | 1.60 | $ | 175,470 | ||||||||||||||||||||||
Year ended December 31, 2020 | $ | 1.60 | $ | 174,873 | ||||||||||||||||||||||
Preferred Units. Distributions on our preferred units are payable out of any legally available funds, accrue and are cumulative from the original issuance dates, and are payable on the 15th day (or next business day) of each of March, June, September and December of each year to holders of record on the first business day of each payment month. Please see Notes 17 and 18 of the Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplementary Data” for additional information.
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The following table provides the terms related to distributions for our Series A, Series B and Series C Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Units (collectively, the Series A, B and C Preferred Units):
| Units | Fixed Distribution Rate Per Annum (as a Percentage of the $25.00 Liquidation Preference Per Unit) | Fixed Distribution Rate Per Unit Per Annum | Fixed Distribution Per Annum | Optional Redemption Date/Date at Which Distribution Rate Becomes Floating | Floating Annual Rate (as a Percentage of the $25.00 Liquidation Preference Per Unit) | |||||||||||||||||||||||||||
| (Thousands of Dollars) | ||||||||||||||||||||||||||||||||
| Series A Preferred Units | 8.50% | $ | 2.125 | $ | 19,252 | December 15, 2021 | Three-month LIBOR plus 6.766% | |||||||||||||||||||||||||
| Series B Preferred Units | 7.625% | $ | 1.90625 | $ | 29,357 | June 15, 2022 | Three-month LIBOR plus 5.643% | |||||||||||||||||||||||||
| Series C Preferred Units | 9.00% | $ | 2.25 | $ | 15,525 | December 15, 2022 | Three-month LIBOR plus 6.88% | |||||||||||||||||||||||||
The Series A Preferred Units switched from a fixed distribution rate to a floating rate on December 15, 2021, with the floating rate set forth below for the period indicated:
| Period | Distribution Rate per Unit | Total Distribution | ||||||||||||
| (Thousands of Dollars) | ||||||||||||||
| December 15, 2021 - March 14, 2022 | $ | 0.43606 | $ | 3,951 | ||||||||||
The distribution rates on the 23,246,650 Series D Preferred Units issued and outstanding are as follows: (i) 9.75%, or $57.6 million, per annum ($0.619 per unit per distribution period) for the first two years (beginning with the September 17, 2018 distribution); (ii) 10.75%, or $63.4 million, per annum ($0.682 per unit per distribution period) for years three through five; and (iii) the greater of 13.75%, or $81.1 million, per annum ($0.872 per unit per distribution period) or the distribution per common unit thereafter. While the Series D Preferred Units are outstanding, the Partnership will be prohibited from paying distributions on any junior securities, including the common units, unless full cumulative distributions on the Series D Preferred Units (and any parity securities) have been, or contemporaneously are being, paid or set aside for payment through the most recent Series D Preferred Unit distribution payment date. Any Series D Preferred Unit distributions in excess of $0.635 may be paid, in the Partnership’s sole discretion, in additional Series D Preferred Units, with the remainder paid in cash. If we fail to pay in full any Series D Preferred Unit distribution amount, then, until we pay such distributions in full, the applicable distribution rate for those distribution periods shall be increased by $0.048 per Series D Preferred Unit. We would also be subject to other requirements.
In January 2022, our board of directors declared quarterly distributions with respect to the Series A, B and C Preferred Units and the Series D Preferred Units to be paid on March 15, 2022.
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Debt Obligations
The following table summarizes our debt obligations:
| Maturity | Outstanding Obligations as of December 31, 2021 | ||||||||||||||||
| (Thousands of Dollars) | |||||||||||||||||
Revolving Credit Agreement, 2.9% as of December 31, 2021 | April 27, 2025 (a) | $ | 110,500 | ||||||||||||||
| 5.75% senior notes | October 1, 2025 | $ | 600,000 | ||||||||||||||
| 6.00% senior notes | June 1, 2026 | $ | 500,000 | ||||||||||||||
| 5.625% senior notes | April 28, 2027 | $ | 550,000 | ||||||||||||||
| 6.375% senior notes | October 1, 2030 | $ | 600,000 | ||||||||||||||
Subordinated notes, 6.9% as of December 31, 2021 | January 15, 2043 | $ | 402,500 | ||||||||||||||
| GoZone Bonds 5.85% - 6.35% | 2038 | thru | 2041 | $ | 322,140 | ||||||||||||
Receivables Financing Agreement, 2.3% as of December 31, 2021 | January 31, 2025 (a) | $ | 83,800 | ||||||||||||||
(a)On January 28, 2022, the maturity date on the Revolving Credit Agreement was extended from October 27, 2023 to April 27, 2025 and the scheduled termination date of the Receivables Financing Agreement was extended from September 20, 2023 to January 31, 2025.
On November 1, 2021, we repaid our $250.0 million of 4.75% senior notes due February 1, 2022 with proceeds from the Eastern U.S. Terminals Disposition. We used borrowings under our Revolving Credit Agreement to repay our $300.0 million of 6.75% senior notes due February 1, 2021 at maturity and our $450.0 million of 4.8% senior notes due September 1, 2020 at maturity.
On June 3, 2020, NuStar Logistics completed the reoffering and conversion of the GoZone Bonds, which, among other things, converted the interest rate from a weekly rate to a long-term rate. We did not receive any proceeds from the reoffering, and the reoffering did not increase our outstanding debt. As reflected in the table below, certain series of GoZone Bonds in principal amounts totaling $75.0 million and $103.8 million contain a requirement for the bondholders to tender their bonds in exchange for 100% of the principal plus accrued and unpaid interest on June 1, 2025 and on June 1, 2030, respectively, after which these bonds will potentially be remarketed with a new interest rate established.
The following table summarizes the GoZone Bonds outstanding as of December 31, 2021:
| Series | Date Issued | Amount Outstanding | Interest Rate | Mandatory Purchase Date | Maturity Date | |||||||||||||||||||||||||||
| (Thousands of Dollars) | ||||||||||||||||||||||||||||||||
| Series 2008 | June 26, 2008 | $ | 55,440 | 6.10 | % | June 1, 2030 | June 1, 2038 | |||||||||||||||||||||||||
| Series 2010 | July 15, 2010 | 100,000 | 6.35 | % | n/a | July 1, 2040 | ||||||||||||||||||||||||||
| Series 2010A | October 7, 2010 | 43,300 | 6.35 | % | n/a | October 1, 2040 | ||||||||||||||||||||||||||
| Series 2010B | December 29, 2010 | 48,400 | 6.10 | % | June 1, 2030 | December 1, 2040 | ||||||||||||||||||||||||||
| Series 2011 | August 9, 2011 | 75,000 | 5.85 | % | June 1, 2025 | August 1, 2041 | ||||||||||||||||||||||||||
| Total | $ | 322,140 | ||||||||||||||||||||||||||||||
We believe that, as of December 31, 2021, we are in compliance with the ratios and covenants applicable to our debt obligations. A default under certain of our debt agreements would be considered an event of default under other of our debt obligations.
Guarantor Summarized Financial Information. NuStar Energy has no operations, and its assets consist mainly of its 100% ownership interest in its indirectly owned subsidiaries, NuStar Logistics and NuPOP. The senior and subordinated notes issued by NuStar Logistics are fully and unconditionally guaranteed by NuStar Energy and NuPOP. Each guarantee of the senior notes by NuStar Energy and NuPOP ranks equally in right of payment with all other existing and future unsecured senior indebtedness of that guarantor, is structurally subordinated to all existing and any future indebtedness and obligations of any subsidiaries of that guarantor that do not guarantee the notes and rank senior to its guarantee of our subordinated indebtedness. Each guarantee of the subordinated notes by NuStar Energy and NuPOP ranks equal in right of payment with all other existing and future subordinated indebtedness of that guarantor and subordinated in right of payment and upon liquidation to the prior payment in full of all other existing and future senior indebtedness of that guarantor. NuPOP will be released from its guarantee
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when it no longer guarantees any obligations of NuStar Energy or any of its subsidiaries, including NuStar Logistics, under any bank credit facility or public debt instrument. The rights of holders of our senior and subordinated notes may be limited under the U.S. Bankruptcy Code or state fraudulent transfer or conveyance law.
The following table presents summarized combined income statement and balance sheet information for NuStar Energy, NuStar Logistics and NuPOP (collectively, the Guarantor Issuer Group). Intercompany items among the Guarantor Issuer Group have been eliminated in the summarized combined financial information below, as well as intercompany balances and activity for the Guarantor Issuer Group with non-guarantor subsidiaries, including the Guarantor Issuer Group’s investment balances in non-guarantor subsidiaries.
| Guarantor Issuer Group | |||||
| (Thousands of Dollars) | |||||
Summarized Combined Balance Sheet Information as of December 31, 2021: | |||||
| Current assets | $ | 33,645 | |||
| Long-term assets | $ | 2,791,481 | |||
| Current liabilities (a) | $ | 119,841 | |||
| Long-term liabilities, including long-term debt | $ | 3,162,351 | |||
| Series D preferred limited partners | $ | 616,439 | |||
Summarized Combined Income Statement Information for the year ended December 31, 2021: | |||||
| Revenues | $ | 837,493 | |||
| Operating income | $ | 244,975 | |||
| Interest expense, net | $ | (214,836) | |||
| Net income | $ | 33,704 | |||
(a)Excluding $1,004.5 million of net intercompany payables due to the non-guarantor subsidiaries from the Guarantor Issuer Group.
Long-term assets for the non-guarantor subsidiaries totaled $2,180.3 million as of December 31, 2021. Revenue and net income for the non-guarantor subsidiaries totaled $781.0 million and $4.5 million, respectively, for the year ended December 31, 2021. Please refer to Note 12 of the Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplementary Data” for a discussion of our debt agreements.
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Contractual Obligations
The following table presents our contractual obligations and commitments as of December 31, 2021:
| Current | Long-Term | ||||||||||
| (Thousands of Dollars) | |||||||||||
| Long-term debt maturities | $ | — | $ | 3,168,940 | |||||||
| Interest payments (a) | 192,461 | 1,705,420 | |||||||||
| Operating leases (b) | 12,252 | 84,739 | |||||||||
| Finance leases (b) | 5,831 | 71,724 | |||||||||
| Purchase obligations (c) | 10,606 | 15,122 | |||||||||
| Total | $ | 221,150 | $ | 5,045,945 | |||||||
(a)The interest payments calculated for our variable-rate, long-term debt are based on interest rates and the outstanding borrowings as of December 31, 2021. The interest payments on our fixed-rate debt are based on the stated interest rates and the outstanding borrowings as of December 31, 2021. Please see Note 12 of the Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplementary Data” for additional information.
(b)Our operating leases consist primarily of land and dock leases at various terminal facilities and leases for marine vessels at our Point Tupper terminal facility. Our finance leases consist primarily of a dock lease at our Corpus Christi North Beach terminal facility with a remaining term of approximately four years and three additional five-year renewal periods that also includes a commitment for minimum dockage and wharfage throughput volumes. Please see Note 15 of the Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplementary Data” for additional information on our operating and finance leases.
(c)A purchase obligation is an enforceable and legally binding agreement to purchase goods or services that specifies significant terms, including (i) fixed or minimum quantities to be purchased, (ii) fixed, minimum or variable price provisions and (iii) the approximate timing of the transaction. Please see Note 14 of the Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplementary Data” for additional information on our purchase obligations.
Series D Preferred Units Redemption Features
We may redeem all or any portion of the 23,246,650 Series D Preferred Units issued and outstanding, in an amount not less than $50.0 million for cash at a redemption price equal to, as applicable: (i) $31.73 per Series D Preferred Unit, or up to $737.6 million, at any time on or after June 29, 2023 but prior to June 29, 2024; (ii) $30.46 per Series D Preferred Unit, or up to $708.1 million, at any time on or after June 29, 2024 but prior to June 29, 2025; (iii) $29.19 per Series D Preferred Unit, or up to $678.6 million, at any time on or after June 29, 2025; plus, in each case, the sum of any unpaid distributions on the applicable Series D Preferred Unit plus the distributions prorated for the number of days elapsed (not to exceed 90) in the period of redemption (Series D Partial Period Distributions). The holders have the option to convert the units prior to such redemption as discussed in Note 17 of the Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplementary Data.”
Additionally, at any time on or after June 29, 2028, each holder of Series D Preferred Units will have the right to require us to redeem all of the Series D Preferred Units held by such holder at a redemption price equal to $29.19 per Series D Preferred Unit, or approximately $678.6 million if all Series D Preferred Units are tendered, plus any unpaid Series D distributions plus the Series D Partial Period Distributions. If a holder of Series D Preferred Units exercises its redemption right, we may elect to pay up to 50% of such amount in common units (which shall be valued at 93% of a volume-weighted average trading price of the common units); provided, that the common units to be issued do not, in the aggregate, exceed 15% of NuStar Energy’s common equity market capitalization at the time.
Environmental, Health and Safety
As described below under “Environmental, Health, Safety and Security Regulation,” our operations are subject to extensive international, federal, state and local environmental laws and regulations, in the U.S. and in the other countries in which we operate, including those relating to the discharge of materials into the environment, waste management, remediation, the characteristics and composition of fuels, climate change and greenhouse gases. Our operations are also subject to extensive health, safety and security laws and regulations, including those relating to worker and pipeline safety, pipeline and storage tank integrity and operations security. Because more stringent environmental and safety laws and regulations are continuously being enacted or proposed, the level of expenditures required for environmental, health and safety matters is expected to increase in the future.
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The balance of and changes in our accruals for environmental matters as of and for the years ended December 31, 2021 and December 31, 2020 are included in Note 13 of the Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplementary Data.” We believe that we have adequately accrued for our environmental exposures.
Contingencies
We are subject to certain loss contingencies, and we believe that the resolution of any particular claim or proceeding, or all matters in the aggregate, would not have a material adverse effect on our results of operations, financial position or liquidity, as further disclosed in Note 14 of the Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplementary Data.”
HUMAN CAPITAL
We strive to make NuStar a safe, positive, inclusive and rewarding workplace, with competitive compensation, benefits and health and wellness programs and opportunities for our employees to grow and develop in their careers.
Our Employees
As of December 31, 2021, we have 1,267 employees, of which 1,187 are based in the United States, 69 are based in Canada and 11 are based in Mexico. Four and a half percent of our 1,267 employees are represented under collective bargaining agreements. In the United States, 496 of our employees work at our headquarters in San Antonio, Texas, with the remaining 691 employees working at other locations.
We believe that having a workforce composed of diverse employees with wide-ranging backgrounds, experiences and ideas makes our company stronger. As of December 31, 2021:
•19.8% of all of our employees and 31.2% of our employees at senior manager level and above are female; and
•31.6% of our U.S. employees and 23.9% of our U.S. employees at senior manager level and above are minorities (as defined by the U.S. Equal Opportunity Employment Commission).
Employee Benefits and NuStar’s Culture
We provide opportunities for our employees to develop and enhance their skills through defined career paths, professional training, educational reimbursement and leadership and development programs, as well as regular training regarding safety, operations, ethics (including our Code of Business Conduct and Ethics), human resources topics and cybersecurity. In addition, we support our employees by providing competitive compensation, benefits and health and wellness programs, including life and health insurance (medical, dental and vision), prescription drug benefits, flexible spending accounts, paid sick leave, vacation, short-term and long-term disability, mental and behavioral health resources, retirement benefits, educational reimbursement, a disaster relief fund, an employee assistance program and employee recognition programs. We also are committed to supporting the communities in which we operate, and we organize opportunities for our employees to participate in and enrich our communities through a variety of initiatives, such as fundraising activities, community clean-up projects and educational programs.
NuStar’s culture revolves around our nine guiding principles: safety; integrity; commitment; make a difference; teamwork; respect; communication; excellence; and pride. We believe that these principles are the building blocks for NuStar’s success and have helped us to recruit and retain our employees and make NuStar a great place to work. NuStar has been recognized on FORTUNE’S “100 Best Companies to Work For” list 12 times, FORTUNE’S “Best Workplaces for Millennials” list five times and was also recognized in 2021 on Latino Leader Magazine’s “Best Companies for Latinos to Work” list. NuStar also has been recognized as a top employer by regional and local publications. Many of these awards are based on confidential surveys of our employees. In addition, we monitor our ability to retain our employees through our voluntary turnover rate (the percentage of our total employees who voluntarily leave our company, other than through retirement). As of December 31, 2021, our voluntary turnover rate was 4.4%, and 251 of our employees have been employed by NuStar or predecessor entities for at least 20 years.
Safety
As a midstream energy company, safety is our first priority. In managing our business, we focus on the safety of our employees and contractors, as well as the communities in which we operate. We have implemented safety programs and management practices to promote a culture of safety, including required training for field and office employees and contractors, as well as specific qualifications and certifications for field employees and contractors. To further emphasize the importance of safety at NuStar, our Board of Directors receives a comprehensive annual report and monthly updates regarding our health, safety and environmental performance. The Compensation Committee of our Board of Directors also evaluates our overall environmental, social and governance (ESG) performance and our health, safety and environmental performance together annually as one of
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the metrics used to determine the annual incentive bonus for all of our employees, including our executive officers, which we believe reinforces the importance of maintaining safe, responsible operations and focusing on ESG excellence.
We are proud of NuStar’s safety performance. Our safety statistics have been substantially better than those reported by the U.S. Bureau of Labor Statistics (BLS) for our industries. Our 2021 total recordable incident rate (TRIR) of 0.13 was 14.6 times better than the 1.9 average most recently reported by BLS for the bulk terminals industry and 7.7 times better than the 1.0 average most recently reported by BLS for the pipeline transportation industry, while our 2021 days away, restricted or transferred rate (DART) of 0.0 far exceeds the 1.5 average most recently reported by BLS for the bulk terminals industry and the 0.5 average most recently reported by BLS for the pipeline transportation industry. NuStar also participates in the Occupational Health and Safety Administration’s (OSHA) Voluntary Protection Program (VPP), which promotes effective worksite health and safety. Achieving VPP Star status requires rigorous OSHA review and audit, and requires recertification every three to five years. As of December 31, 2021, approximately 91% of our eligible U.S. terminals have attained VPP Star status. NuStar also has received the International Liquids Terminals Association’s Safety Excellence Award 11 times. Throughout the COVID-19 pandemic, we have continued to focus on safety and have taken measures to protect our employees and maintain safe, reliable operations to continue supplying the energy our country needs.
Sustainability Report
During 2021, we published our inaugural Sustainability Report, which also covers topics similar to those described above, including our guiding principles; operations and economic impact; COVID-19 pandemic response; environmental and safety programs, policies and statistics; employee engagement, development and training; diversity and inclusion; community involvement; recent awards; human rights and indigenous communities; and governance matters. Our Sustainability Report can be viewed at https://sustainability.nustarenergy.com. Information contained on our website is not part of this Annual Report on Form 10-K.
PROPERTIES
Our principal properties are described above under the caption “Segments and Results of Operations” above, and that information is incorporated herein by reference. We believe that we have satisfactory title to all of our properties. Although title to these properties is subject to encumbrances in some cases, such as customary interests generally retained in connection with the acquisition of real property, liens for current taxes and other burdens and easements, and restrictions or other encumbrances, including those related to environmental liabilities associated with historical operations, to which the underlying properties were subject at the time of acquisition by us or our predecessors, we believe that none of these burdens will materially detract from the value of these properties or from our interest in these properties or will materially interfere with their use in the operation of our business. In addition, we believe that we have obtained sufficient right-of-way grants and permits from public authorities and private parties for us to operate our business in all material respects as described in this report. We perform scheduled maintenance on all of our pipelines, terminals, crude oil tanks and related equipment and make repairs and replacements when necessary or appropriate. We believe that our pipelines, terminals, crude oil tanks and related equipment have been constructed and are maintained in all material respects in accordance with applicable federal, state and local laws and the regulations and standards prescribed by the American Petroleum Institute, the DOT and accepted industry practice.
RATE REGULATION
Several of our crude oil and refined products pipelines are interstate common carrier pipelines, which are subject to regulation by the FERC under the Interstate Commerce Act (ICA) and the Energy Policy Act of 1992 (the EP Act). The ICA and its implementing regulations give the FERC authority to regulate the rates charged for service on interstate common carrier pipelines and generally require the rates and practices of interstate liquids pipelines to be just, reasonable, not unduly discriminatory and not unduly preferential. The ICA also requires tariffs that set forth the rates a common carrier pipeline charges for providing transportation services on its interstate common carrier liquids pipelines, as well as the rules and regulations governing these services, to be maintained on file with the FERC and posted publicly. The EP Act deemed certain rates in effect prior to its passage to be just and reasonable and limited the circumstances under which a complaint can be made against such “grandfathered” rates. The EP Act and its implementing regulations also allow interstate common carrier liquids pipelines to annually index their rates up to a prescribed ceiling level and require that such pipelines index their rates down to the prescribed ceiling level if the index is negative. In addition, the FERC retains cost-of-service ratemaking, market-based rates and settlement rates as alternatives to the indexing approach.
Our ammonia pipeline is subject to regulation by the STB pursuant to the ICA applicable to such pipelines (which differs from the ICA applicable to interstate liquids pipelines). Under that regulation, the ammonia pipeline’s rates, classifications, rules and practices related to the interstate transportation of anhydrous ammonia must be reasonable and, in providing interstate
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transportation, the ammonia pipeline may not subject a person, place, port or type of traffic to unreasonable discrimination. Similar to the crude and refined products pipelines, the rates for transportation services on the ammonia pipeline are required to be in a tariff which is posted publicly on our website, however, that tariff is not required to be on file with the STB. The STB does not prescribe an indexing approach similar to the EP Act but rates under the STB must be reasonable and the pipeline may not subject a person, place, port or type of traffic to unreasonable discrimination.
In addition to federal regulatory body oversight, various states, including Colorado, Kansas, Louisiana, North Dakota and Texas, maintain commissions focused on the rates and practices of common carrier pipelines offering services within their borders. Although the applicable state statutes and regulations vary, they generally require that intrastate pipelines publish tariffs setting forth all rates, rules and regulations applying to intrastate service, and generally require that pipeline rates and practices be just, reasonable and nondiscriminatory.
Shippers may challenge tariff rates, rules and regulations on our pipelines. In most instances, state commissions have not initiated investigations of the rates or practices of pipelines in the absence of shipper complaints. There are no pending challenges or complaints regarding our tariffs or tariff rates.
ENVIRONMENTAL, HEALTH, SAFETY AND SECURITY REGULATION
Our operations are subject to extensive international, federal, state and local environmental laws and regulations, in the U.S. and in the other countries in which we operate, including those relating to the discharge of materials into the environment, waste management, remediation, the characteristics and composition of fuels, climate change and greenhouse gases. In 2021, our capital expenditures attributable to compliance with environmental regulations were $6.4 million, and we currently project environmental regulatory compliance spending of approximately $6.8 million in 2022.
Our operations are also subject to extensive health, safety and security laws and regulations, including those relating to worker and pipeline safety, pipeline and storage tank integrity and operations security. The principal environmental, health, safety and security risks associated with our operations relate to unauthorized emissions into the air, releases into soil, surface water or groundwater, personal injury and property damage. We have adopted policies, practices, systems and procedures designed to comply with the laws and regulations, and to help minimize and mitigate these risks, limit the liability that could result from such events, prevent material environmental or other damage, ensure the safety of our employees and the public and secure our pipelines, terminals and operations. Compliance with environmental, health, safety and security laws, regulations and related permits increases our capital expenditures and operating expenses, and violation of these laws, regulations or permits could result in significant civil and criminal liabilities, injunctions or other penalties. Future governmental actions could result in more restrictive laws and regulations, which could increase required capital expenditures and operating expenses. At this time, we are unable to estimate either the impact, if any, of potential future regulation and/or legislation on our financial condition or results of operations, or the amount and timing of such possible future expenditures or expenses. The risk of additional compliance expenditures, expenses and liabilities are inherent to government-regulated industries, including midstream energy. As a result, there can be no assurances that significant expenditures, expenses and liabilities will not be incurred in the future. However, while compliance may affect our capital expenditures and operating expenses, we believe that the cost of such compliance will not have a material impact on our competitive position, financial condition or results of operations. Further, we do not believe that our cost of compliance is proportionately greater than the cost to other companies operating in our industry.
Discussed below are the primary U.S. environmental, health, safety and security laws applicable to our operations. Compliance with or violations of any of these laws and related regulations could result in significant expenditures, expenses and liabilities.
Occupational, Safety and Health
We are subject to the Occupational Safety and Health Act, as amended, and analogous or more stringent international, state and local laws and regulations for the protection of worker safety and health. In addition, we have operations subject to the Occupational Safety and Health Administration’s Process Safety Management regulations. These regulations apply to processes that involve certain chemicals at or above specified thresholds.
Fuel Standards and Renewable Energy
International, federal, state and local laws and regulations regulate the fuels we transport and store for our customers. Changes in these laws or regulations could affect our earnings, including by reducing our throughput volumes, or require capital expenditures and expenses to segregate and separately store fuels. In addition, several federal and state programs require, subsidize or encourage the purchase and use of competing fuels or energy, renewable energy, electric battery-powered motor vehicle engines and renewable fuels and blending additives, like ethanol, biodiesel and renewable diesel. These programs may over time offset projected increases or reduce the demand for refined products, particularly gasoline, in certain markets. However, the increased production and use of renewable fuels may also create opportunities for pipeline transportation and fuel
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blending. Other legislative changes in the future may similarly alter the expected demand and supply projections for refined products in ways that cannot be predicted.
Hazardous Substances and Hazardous Waste
The Federal Comprehensive Environmental Response, Compensation and Liability Act, referred to as CERCLA or “Superfund,” and analogous or more stringent international, state and local laws and regulations, impose restrictions and liability related to the release, threatened release, disposal and remediation of hazardous substances. This liability can be joint and several strict liability, without regard to fault or the legality of the original release or disposal. Current operators of a facility, past owners or operators of a facility and parties who arranged for the disposal of a hazardous substance can be held liable under these laws and regulations.
We currently own, lease, and operate on, and have in the past owned, leased and operated on, properties and at facilities that handled, transported and stored hazardous substances. Despite our compliance with applicable requirements and industry standards, hazardous substances may have been released on or under our facilities and properties, or on or under locations where these substances were taken for disposal. We are currently remediating subsurface contamination at several facilities, and, based on currently available information, we believe the costs related to these remedial activities should not materially affect our financial condition or results of operations. However, the aggregate total cost of remediation projects can be difficult to estimate, and there are no assurances that the cost of future remedial activities will not become material. Further, applicable laws or regulation, including those dictating the degree of remediation required, may be revised to be more restrictive in the future. As a result, we are unable to estimate the effect of future regulation on our financial condition or results of operations or the amount and timing of future expenditures required to comply with such possible regulatory changes.
The Federal Resource Conservation and Recovery Act, as amended, and analogous or more stringent international, state and local laws and regulations impose restrictions and strict controls regarding the handling and disposal of wastes, including hazardous wastes. We generate hazardous wastes and it is possible that additional wastes, which could include wastes currently generated during operations, will be designated as hazardous wastes in the future. Hazardous wastes are subject to more rigorous requirements than are non-hazardous wastes.
Air
The Federal Clean Air Act, as amended, and various applicable international, state and local laws and regulations impose restrictions and strict controls regarding emission into the air, including greenhouse gas emissions. These laws and regulations generally require permits issued by applicable federal, state or local authorities for emissions, and impose monitoring and reporting requirements. Such laws and regulations can also require pre-approval for the construction or modification of certain operations or facilities expected to produce or increase air emissions.
Water
The Federal Water Pollution Control Act, as amended, also known as the Clean Water Act, the federal Spill Prevention, Control, and Countermeasure and Facility Response Plan Rules and analogous or more stringent international, state and local laws and regulations impose restrictions and strict controls regarding the discharge of pollutants into state waters or waters of the United States. The discharge of pollutants into waters is generally prohibited, except in accordance with a permit issued by applicable federal or state authorities. The Oil Pollution Act further regulates the discharge of oil, and the response to and liability for oil spills, and the Rivers and Harbors Act regulates pipelines crossing navigable waters.
Pipeline and Other Asset Integrity, Safety and Security
Our pipeline, storage tank and other operations are subject to extensive international, federal, state and local laws and regulations governing integrity, safety and security, including those in Title 49 of the U.S. Code and its implementing regulations. These laws and regulations include the Pipeline and Hazardous Materials Safety Administration’s requirements for safe pipeline design, construction, operation, maintenance, inspection, testing and corrosion control, control rooms and qualification programs for operating personnel. In addition, we have marine terminal operations subject to Coast Guard safety, integrity and security regulations and standards. We also have operations subject to the Department of Homeland Security Chemical Facility Anti-Terrorism Standards and security guidelines and directives issued by the Transportation Security Administration.
Although we take proactive steps to protect our company, systems and data from cyberattacks, such as implementing multiple layers of security, segregated systems and user access, antivirus tools, vulnerability scanning, monitoring and patch management, regular employee training, phishing tests, penetration tests, internal risk assessments, independent third-party assessments, tabletop exercises to test our incident response plan, enhanced cyber diligence of vendors and physical security measures, all companies are at risk of a cyberattack. Due to the continued acceleration of cyberattacks, generally and against our industry, regulatory actions by federal, state and local governmental agencies in the U.S. and in other countries in which we operate have increased. Although we believe that we have robust cybersecurity procedures and other safeguards in place, we
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cannot guarantee their effectiveness, and a significant failure, compromise, breach or interruption in our systems or those of our customers or vendors could have a material effect on our operations and the operations of our customers and vendors.
CRITICAL ACCOUNTING POLICIES
The preparation of financial statements in accordance with U.S. generally accepted accounting principles requires management to select accounting policies and to make estimates and assumptions related thereto that affect the amounts reported in the consolidated financial statements and accompanying notes. Actual results could differ from those estimates. The accounting policies below are considered critical due to judgments made by management and the sensitivity of these estimates to deviations of actual results from management’s assumptions. Ongoing uncertainty surrounding the COVID-19 pandemic, including its duration and lingering impacts, and uncertainty surrounding future production decisions by oil-producing nations continue to cause volatility and could significantly impact management’s estimates and assumptions. The critical accounting policies should be read in conjunction with Note 2 of the Notes to the Consolidated Financial Statements in Item 8. “Financial Statements and Supplementary Data,” which summarizes our significant accounting policies.
Impairment of Long-Lived Assets
We test long-lived assets for recoverability whenever events or changes in circumstances indicate that the carrying amount of the asset may not be recoverable. We evaluate recoverability using undiscounted estimated net cash flows generated by the related asset or asset group. If the results of that evaluation indicate that the undiscounted cash flows are less than the carrying amount of the asset (i.e., the asset is not recoverable) we perform an impairment analysis. If our intent is to hold the asset for continued use, we determine the amount of impairment as the amount by which the net carrying value exceeds its fair value. If our intent is to sell the asset, and the criteria required to classify an asset as held for sale are met, we determine the amount of impairment as the amount by which the net carrying amount exceeds its fair value less costs to sell.
In determining the existence of an impairment of the carrying value of an asset, we make a number of subjective assumptions as to:
•whether there is an event or circumstance that may indicate that the carrying amount of an asset may not be recoverable;
•the grouping of assets;
•the intention of holding, abandoning or selling an asset;
•the forecast of undiscounted expected future cash flows with respect to an asset or asset group; and
•if an impairment exists, the fair value of the asset or asset group.
Our estimates of undiscounted future cash flows include: (i) discrete financial forecasts, which rely on management’s estimates of revenue and operating expenses; (ii) long-term growth rates; and (iii) estimates of useful lives of the assets. The identification of impairment indicators and the estimates of future undiscounted cash flows are highly subjective and are based on numerous assumptions about future operations and market conditions, which we believe to be reasonable but are inherently uncertain. The uncertainties underlying our assumptions and estimates could differ significantly from actual results and could cause a different conclusion about the recoverability of our assets. If we determined one or more assets was impaired, the amount of impairment could be material to our results of operations.
We recorded long-lived asset impairment charges of $154.9 million in 2021 and $305.7 million in 2019. Please refer to Note 4 of the Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplementary Data,” for discussion of the impairment charges.
Impairment of Goodwill
We perform an assessment of goodwill annually or more frequently if events or changes in circumstances warrant. We have the option to first perform a qualitative annual assessment to determine whether it is necessary to perform a quantitative goodwill impairment test. A qualitative assessment includes, among other things, industry and market considerations, overall financial performance, other entity-specific events and events affecting individual reporting units. If after assessing the totality of events or circumstances for each reporting unit, we determine that it is more likely than not that the carrying value exceeds its fair value, then we would perform a quantitative impairment test for that reporting unit.
We recognize an impairment of goodwill if the carrying value of a reporting unit that contains goodwill exceeds its estimated fair value. In order to estimate the fair value of the reporting unit, including goodwill, management must make certain estimates and assumptions that affect the total fair value of the reporting unit including, among other things, an assessment of market conditions, projected cash flows, discount rates and growth rates. Management’s estimates of projected cash flows related to the reporting unit include, but are not limited to, future earnings of the reporting unit, assumptions about the use or disposition of
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assets included in the reporting unit, estimated remaining lives of those assets, and future expenditures necessary to maintain the assets’ existing service potential.
We calculate the estimated fair value of each of our reporting units using a weighted-average of values calculated using an income approach and a market approach. The income approach involves estimating the fair value of each reporting unit by discounting its estimated future cash flows using a discount rate, consistent with a market participant’s assumption. The market approach bases the fair value measurement on information obtained from observed stock prices of public companies and recent merger and acquisition transaction data of comparable entities. Our fair value estimates are sensitive to typical valuation assumptions, particularly our estimates for the weighted-average cost of capital used for the income approach and the guideline public company and guideline transaction multiples used for the market approach.
We recorded goodwill impairment charges of $34.1 million, $225.0 million and $31.1 million for the years ended December 31, 2021, 2020 and 2019, respectively. Please refer to Notes 4 and 10 of the Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplementary Data,” for discussion of the impairment charges.
Defined Benefit Plans
We estimate pension and other postretirement benefit obligations and costs based on actuarial valuations. The annual measurement date for our pension and other postretirement benefit plans is December 31. The actuarial valuations require the use of certain assumptions including discount rates, expected long-term rates of return on plan assets and expected rates of compensation increase. Changes in these assumptions are primarily influenced by factors outside our control. The discount rate is based on a hypothetical yield curve represented by a series of annualized individual discount rates. Each bond issue underlying the hypothetical yield curve required an average rating of double-A, when averaging all available ratings by Moody’s Investor Service Inc., S&P Global Ratings and Fitch Ratings. The expected long-term rate of return on plan assets is based on the weighted averages of the expected long-term rates of return for each asset class of investments held in our plans as determined using historical data and the assumption that capital markets are informationally efficient. The expected rate of compensation increase represents average long-term salary increases.
These assumptions can have an effect on the amounts reported in our consolidated financial statements. A 0.25% change in the specified assumptions would have the following effects (thousands of dollars):
| Pension Benefits | Other Postretirement Benefits | ||||||||||
Increase in benefit obligation as of December 31, 2021 resulting from: | |||||||||||
| Discount rate decrease | $ | 6,900 | $ | 600 | |||||||
| Compensation rate increase | $ | 600 | n/a | ||||||||
Increase in net periodic benefit cost for the year ending December 31, 2022 resulting from: | |||||||||||
| Discount rate decrease | $ | 500 | $ | 100 | |||||||
| Expected long-term rate of returns on plan assets decrease | $ | 400 | n/a | ||||||||
| Compensation rate increase | $ | 200 | n/a | ||||||||
Please refer to Note 21 of the Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplementary Data” for further discussion of our pension and other postretirement benefit obligations.
Environmental Liabilities
Environmental remediation costs are expensed and an associated accrual is established when site restoration and environmental remediation and cleanup obligations are either known or considered probable and can be reasonably estimated. These environmental obligations are based on estimates of probable undiscounted future costs using currently available technology and applying current regulations, as well as our own internal environmental policies. The environmental liabilities have not been reduced by possible recoveries from third parties. Environmental costs include initial site surveys, costs for remediation and restoration and ongoing monitoring costs, as well as fines, damages and other costs, when estimable. Adjustments to initial estimates are recorded, from time to time, to reflect changing circumstances and estimates based upon additional information developed in subsequent periods. Environmental liabilities are difficult to assess and estimate due to unknown factors, such as the timing and extent of remediation, the determination of our liability in proportion to other parties, improvements in cleanup technologies and the extent to which environmental laws and regulations may change in the future. We believe that we have
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adequately accrued for our environmental exposures. Please refer to Note 13 of the Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplementary Data” for the amount of accruals for environmental matters.
Contingencies
We accrue for costs relating to litigation, claims and other contingent matters when such liabilities become probable and reasonably estimable. Such estimates may be based on advice from third parties or on management’s judgment, as appropriate. Due to the inherent uncertainty of litigation, actual amounts paid may differ from amounts estimated, and such differences will be charged to income in the period when final determination is made. Please see Note 14 of the Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplementary Data” for additional information on our contingent liabilities.
NEW ACCOUNTING PRONOUNCEMENTS
Management’s Discussion and Analysis, Selected Financial Data, and Supplementary Financial Information
In November 2020, the Securities and Exchange Commission (SEC) issued final rules to modernize, simplify and enhance certain financial disclosure requirements in Regulation S-K. Among other changes, the amended guidance eliminates the requirements to present five-year selected financial data, the two-year quarterly financial data table and the contractual obligations table in the Form 10-K, while it adds requirements to disclose material cash requirements and additional information regarding critical accounting estimates. The rule changes became effective on February 10, 2021, and we are required to apply the amended rules in our filings for the fiscal year ending on December 31, 2021. Early application by amended Regulation S-K item was permitted any time after the effective date. We elected to apply provisions related to selected financial data and quarterly financial information in our Annual Report on Form 10-K for the year ended December 31, 2020 and applied the remaining provisions in our Annual Report on Form 10-K for the year ended December 31, 2021.
Please refer to Note 3 of the Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplementary Data” for a further discussion of new accounting pronouncements.
AVAILABLE INFORMATION
Our internet website address is www.nustarenergy.com. Information contained on our website is not part of this report. Our annual reports on Form 10-K, quarterly reports on Form 10-Q and current reports on Form 8-K, and any amendments thereto, filed with (or furnished to) the SEC are available on our website, free of charge, as soon as reasonably practicable after we file or furnish such material (select the “Investors” link, then the “SEC Filings” link). We also post our corporate governance guidelines, code of business conduct and ethics, code of ethics for senior financial officers and the charters of our board’s committees on our website free of charge (select the “Investors” link, then the “Corporate Governance” link).
Our governance documents are available in print to any unitholder that makes a written request to Corporate Secretary, NuStar Energy L.P., 19003 IH-10 West, San Antonio, Texas 78257 or corporatesecretary@nustarenergy.com.
ITEM 1A. RISK FACTORS
RISKS RELATED TO OUR BUSINESS
The ongoing effects of the COVID-19 pandemic, the actions taken in response thereto and developments in the global oil markets may continue to adversely affect our business, financial condition, results of operations or cash flows.
The coronavirus, or COVID-19, had a severe negative impact on global economic activity during 2020, which significantly reduced demand for petroleum products and increased the volatility of crude oil prices, beginning in March 2020. While a number of countries, including the United States, made significant progress during 2021 deploying COVID-19 vaccines, which has improved the economic conditions and outlook in those nations, many more continue to struggle to obtain and/or disseminate vaccinations to their populace, which continues to frustrate widespread global economic recovery. Even in the United States, if a sufficient proportion of people are not vaccinated, or as variants emerge, we may continue to face surges in COVID-19 cases in some regions, which could slow the pace of domestic economic improvement and undermine demand in the markets our assets serve. The COVID-19 pandemic and other public health crises may also have the effect of heightening many of the other risks described in the risk factors below.
Ongoing uncertainty surrounding the COVID-19 pandemic, including its duration and lingering impacts to the economy, as well as uncertainty surrounding future production decisions by the Organization of Petroleum Exporting Countries and other oil-producing nations (OPEC+), have caused and may continue to cause volatility and could have a significant impact on management’s estimates and assumptions for 2022 and beyond. The extent of the impacts of any of these factors on our business, financial condition, results of operations and cash flows will depend on future developments that are highly uncertain and cannot be accurately predicted, such as: the duration and severity of the COVID-19 pandemic or other public health crises
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and any lingering effect on the economy; uncertainty surrounding future production decisions by OPEC+; the state of the economy and the capital markets; changes to our customers’ refinery maintenance schedules and unplanned refinery downtime; crude oil prices; the supply of and demand for crude oil, refined products, renewable fuels and anhydrous ammonia; demand for our transportation and storage services; the availability and costs of personnel, equipment, supplies and services essential to our operations; the ability to obtain timely permitting approvals; and changes in laws and regulations affecting our business.
We may not be able to generate sufficient cash from operations to enable us to pay quarterly distributions to our unitholders.
The amount of cash that we can distribute to our unitholders each quarter principally depends upon the amount of cash we generate from our operations, based on, among other things:
•prevailing macroeconomic conditions as well as economic conditions in and specific to our primary markets;
•demand for and supply of crude oil, refined products, renewable fuels and anhydrous ammonia;
•volumes transported in our pipelines and stored in our terminals and storage facilities;
•the financial stability and strength of our customers;
•tariff and/or contractually determined rates and fees we charge and the revenue we realize for our services;
•domestic and foreign governmental laws, regulations, sanctions, embargoes and taxes;
•the effect of energy conservation, efficiency and other evolving priorities;
•the effect of weather events on our operations and demand for our services; and
•the results of our marketing, trading and hedging activities, which fluctuate depending upon the relationship between refined product prices and prices of crude oil and other feedstocks.
Furthermore, the amount of cash that we will have available for distribution depends on a number of other factors, including:
•our debt service requirements and restrictions on distributions contained in our current or future financing agreements;
•our capital expenditures;
•our operating costs;
•the costs to comply with environmental, health, safety and security laws and regulations;
•fluctuations in our working capital needs;
•adjustments in cash reserves made by our board of directors, in its discretion;
•availability of and access to equity capital and debt markets; and
•the sources of cash used to fund our acquisitions, if any.
Moreover, the total amount of cash that we have available for distribution to common unitholders is further reduced by the required distributions with respect to our preferred units.
It is possible that one or more of the factors listed above, which may be further impacted by the ongoing COVID-19 pandemic or other public health crises, as well as the actions of oil-producing nations, may reduce our available cash to such an extent that we are unable to pay distributions at the current level or at all in a given quarter. Cash distributions to our unitholders depend primarily upon our cash flows, including cash flows from reserves and working capital borrowings, and not solely on profitability, which is affected by non-cash items; in other words, we may be able to make cash distributions during periods in which we record net losses and may not be able to make cash distributions during periods in which we record net income.
An extended period of reduced demand for or supply of crude oil and refined products could have an adverse impact on our results of operations, cash flows and ability to make distributions to our unitholders.
Our business is ultimately dependent upon the demand for and supply of the crude oil and refined products we transport in our pipelines and store in our terminals. Market prices for crude oil and refined products, including fuel oil, are subject to wide fluctuation in response to changes in global and regional supply that are beyond our control. Increases in the price of crude oil may result in a lower demand for refined products that we transport, store and market, including fuel oil, while sustained low prices may lead to reduced production in the markets served by our pipelines and storage terminals.
Any sustained decrease in demand for refined products in the markets our pipelines and terminals serve that extends beyond the expiration of our existing throughput and deficiency agreements could result in a significant reduction in throughputs in our pipelines and storage in our terminals, which would reduce our cash flows and impair our ability to make distributions to our unitholders. Factors that tend to decrease market demand include:
•a recession, inflation or other adverse economic conditions that result in lower spending by consumers on gasoline, diesel and travel;
•events that negatively impact global economic activity, travel and demand generally, such as has occurred in response to the COVID-19 pandemic;
•higher fuel taxes or other governmental or regulatory actions that increase, directly or indirectly, the cost of gasoline;
•an increase in aggregate automotive engine fuel economy;
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•new government and regulatory actions or court decisions requiring the phase out or reduced use of gasoline-fueled vehicles;
•the increased use of and public demand for use of alternative fuel sources or electric vehicles;
•an increase in the market price of crude oil that increases refined product prices, which may reduce demand for refined products and increase demand for alternative products; and
•a decrease in corn acres planted for ethanol, which may reduce demand for anhydrous ammonia.
Similarly, any sustained decrease in the supply of crude oil and refined products in markets we serve could result in a significant reduction in throughputs in our pipelines and storage in our terminals, which would reduce our cash flows and undermine our ability to make distributions to our unitholders. Factors that tend to decrease supply and, by extension, utilization of our pipelines and terminals include:
•prolonged periods of low prices for crude oil and refined products that result in decreased exploration and development activity and reduced production in markets served by our pipelines and storage terminals;
•macroeconomic forces affecting, or actions taken by, oil and gas producing nations that impact supply of and prices for crude oil and refined products;
•a lack of drilling services, equipment or skilled personnel available to producers to accommodate production needs;
•changes in laws, regulations, sanctions or taxation that directly or indirectly delay supply or production or increase the cost of production of refined products; and
•political unrest or hostilities, activist interference and the resulting governmental response thereto.
Failure to retain or replace current customers and existing contracts to maintain utilization of our pipeline and storage assets at current or more favorable rates could reduce our revenue and cash flows to levels that adversely affect our ability to make quarterly distributions to our unitholders.
Our revenue and cash flows are generated primarily from our customers’ payments of fees under throughput contracts and storage agreements. Failure to renew or enter into new contracts or a material reduction in utilization under existing contracts results from many factors, including:
•sustained low crude oil prices;
•a material decrease in the supply or price of crude oil;
•a material decrease in demand for refined products in the markets served by our pipelines and terminals;
•political, social or economic instability in the United States or another country that has a detrimental impact on customers based there and our ability to conduct our operations;
•competition for customers from companies with comparable assets and capabilities;
•scheduled turnarounds or unscheduled maintenance at customers we serve;
•operational problems or catastrophic events affecting our assets or customers we serve;
•environmental or regulatory proceedings or other litigation that compel the cessation of all or a portion of the operations of our assets or those of the customers we serve;
•increasingly stringent environmental, health, safety and security regulations;
•a decision by our current customers to redirect products transported in our pipelines to markets not served by our pipelines or to transport crude oil or refined products by means other than our pipelines; and
•a decision by our current customers to shut down, limit operations of or sell one or more of the refineries we serve to a purchaser that elects not to use our pipelines and terminals.
Depending on conditions in the credit and capital markets at a given time, we may not be able to obtain funding on acceptable terms or at all, which may hinder or prevent us from meeting our future capital needs, satisfying our debt obligations, or making quarterly distributions to our unitholders.
From time to time, the domestic and global financial markets and economic conditions are volatile and disrupted by a variety of factors, including low consumer confidence, high unemployment, geoeconomic and geopolitical issues, weak economic conditions, uncertainty in the market and negative sentiment toward fossil fuel energy-related companies generally, or master limited partnerships specifically. For example, in light of the ongoing COVID-19 pandemic, global financial markets have experienced significant volatility, which is expected to continue during the pendency of the pandemic. In addition, there are fewer investors and lenders for master limited partnership debt and equity capital market issuances than there are for corporate issuances, and negative public sentiment toward the fossil fuel energy industry has led some investors and lenders to reduce or cease investing in and lending to fossil fuel energy companies. As a result, the cost of raising capital has increased, the availability of funds has diminished and certain lenders have, and others may, refuse to refinance existing debt on similar terms or at all and reduce, or in some cases cease to provide, funding to borrowers such as us.
In general, if we do not generate sufficient cash from operations to finance our expenditures and funding from external sources is not available when needed, or is available only on unfavorable terms, we may be unable to execute our growth strategy, complete future acquisitions or construction projects or take advantage of other business opportunities and may be required to
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reduce investments or capital expenditures or sell assets, which could have a material adverse effect on our revenues and results of operations, and we may not be able to satisfy our debt obligations or pay distributions to our unitholders.
Our future financial and operating flexibility may be adversely affected by our significant leverage, any future downgrades of our credit ratings, restrictions in our debt agreements and conditions in the financial markets.
As of December 31, 2021, our consolidated debt was $3.2 billion, and we have the ability to incur more debt. In addition to any potential direct financial impact of our debt, a material increase to our debt or other adverse financial factors would likely be viewed negatively by credit rating agencies, which could result in ratings downgrades, increased costs or inability for us to access the capital markets and an increase in interest rates on amounts borrowed under our revolving credit agreement and an increase in certain fees on our accounts receivable securitization program.
Our revolving credit agreement contains restrictive covenants, such as limitations on indebtedness, liens, mergers, asset transfers and certain investing activities. In addition, that agreement limits us to a consolidated debt coverage ratio (consolidated debt to consolidated EBITDA, each as defined in the agreement) not to exceed 5.00-to-1.00 and requires us to maintain a minimum consolidated interest coverage ratio (as defined in the agreement) of at least 1.75-to-1.00. Failure to comply with any of the restrictive covenants or the maximum consolidated debt coverage ratio or minimum consolidated interest coverage ratio requirements would constitute an event of default and could result in acceleration of our obligations under our revolving credit agreement and possibly other agreements. Our accounts receivable securitization program, senior notes and other debt obligations also contain various customary affirmative and negative covenants and default, indemnification and termination provisions, and provide for acceleration of amounts owed upon the occurrence of certain specified events. Future financing agreements we may enter into may contain similar or more restrictive covenants and ratio requirements than those we have negotiated for our current financing agreements.
Our debt service obligations, restrictive covenants, ratio requirements and maturities may adversely affect our ability to finance future operations, pursue acquisitions, fund our capital needs and pay cash distributions to our unitholders. In addition, this leverage may make our results of operations more susceptible to adverse economic or operating conditions, limit our flexibility in planning for, or reacting to, changes in our business and industry and place us at a competitive disadvantage compared to competitors with proportionately less indebtedness. For example, during an event of default under certain of our debt agreements, we would be prohibited from making cash distributions to our unitholders.
Our ability to service our debt will depend on, among other things, our future financial and operating performance and our ability to access the capital markets, which will be affected by prevailing economic conditions and financial, business, regulatory and other factors, some of which are beyond our control. If our operating results are not sufficient to service our indebtedness and we are unable to access the capital markets or otherwise refinance our indebtedness, we may be required to reduce our distributions, reduce or delay our business activities, investments or capital expenditures, sell assets or issue additional equity, which could materially and adversely affect our financial condition, results of operations, cash flows and ability to make distributions to unitholders, as well as the trading price of our units.
Changes in interest rates could adversely affect our business and the trading price of our units.
We have significant exposure to increases in interest rates through variable rate provisions in certain of our debt instruments and our Series A, B and C preferred units. At December 31, 2021, we had approximately $3.2 billion of consolidated debt, of which $2.6 billion was at fixed interest rates and $0.6 billion was at variable interest rates. In addition, the distribution rates on our Series A preferred units converted from a fixed rate to a floating rate in December 2021, with our Series B and C preferred units scheduled to convert to a floating rate in June 2022 and December 2022, respectively. Our results of operations, cash flows and financial position could be materially adversely affected by significant changes in interest rates and uncertainty regarding the floating rates referenced in our variable rate debt instruments and preferred units could adversely affect the value of those financing arrangements.
Furthermore, although we have positioned ourselves to self-fund all of our expenses, distribution requirements and capital expenditures for 2022 using internally generated cash flows, we have historically funded our strategic capital expenditures and any acquisitions primarily from borrowings under our revolving credit agreement, funds raised through debt or equity offerings and/or sales of non-strategic assets. An increase in interest rates may also have a negative impact on our ability to access the capital markets at economically attractive rates.
Moreover, the market price of master limited partnership units, like other yield-oriented securities, may be affected by, among other factors, implied distribution yield. The distribution yield is often used by investors to compare and rank yield-oriented securities for investment decision-making purposes. Therefore, increases or decreases in interest rates may affect whether or not certain investors decide to invest in master limited partnership units, including ours, and a rising interest rate environment could have an adverse impact on our unit price and impair our ability to issue additional equity or incur debt to fund growth or for other purposes, including distributions.
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Our inability to develop, fund and execute growth projects and acquire new assets could limit our ability to maintain and grow quarterly distributions to our unitholders.
Our ability to maintain and grow our distributions to unitholders depends on the growth of our existing businesses and strategic acquisitions. Decisions regarding new growth projects rely on numerous estimates, including, among other factors, the ability to secure a commitment from a customer that sufficiently exceeds our cost of capital to justify the project cost, predictions of future demand for our services, future supply shifts, crude oil production estimates, commodity price environments, economic conditions, both domestic and foreign, and potential changes in the financial condition of our customers. Our predictions of such factors could cause us to forego certain investments and to lose opportunities to competitors who make investments based on different predictions or have greater access to financial resources. In addition, volatile market conditions have caused us to reevaluate the estimates underlying certain planned projects and delay the timing of certain projects until conditions improve. If we are unable to develop and execute expansion projects, implement business development opportunities, acquire new assets and finance such activities on economically acceptable terms, our future growth will be limited, which could have a significant adverse impact on our results of operations and cash flows and, accordingly, result in reduced distributions over time.
Failure to complete capital projects as planned adversely affects our financial condition, results of operations and cash flows.
While we incur financing costs during the planning and construction phases of our projects, a project does not generate expected operating cash flows until it is at least substantially completed, if at all. Additionally, our forecasted operating results from capital spending projects are based on future market fundamentals that are not within our control, including changes in general economic conditions, the supply and demand of crude oil, refined products and renewable fuels, availability to our customers of attractively priced alternative solutions for storage, transportation or supplies of crude oil, refined products and renewable fuels and overall customer demand. As a result of these uncertainties, the anticipated benefits associated with our capital projects may not be achieved or could be delayed. In turn, this could have a negative impact on our results of operations and cash flow and our ability to make cash distributions to our unitholders.
Although we evaluate and monitor each capital spending project and try to anticipate difficulties that may arise, delays or cost increases related to capital spending programs involving construction of new facilities (or improvements and repairs to our existing facilities) adversely affect our ability to achieve forecasted operating results. Delays or cost increases arise as a result of many factors that are beyond our control, including:
•adverse economic conditions;
•market-related increases in a project’s debt or equity financing costs;
•severe adverse weather conditions, natural disasters or other events (such as hurricanes, equipment malfunctions, explosions, fires, spills or public health events) affecting our facilities or employees, or those of vendors and suppliers;
•non-performance or delay by, or disputes with, counterparties, vendors, suppliers, contractors or sub-contractors involved with a project;
•denial or delay in issuing requisite regulatory approvals and/or permits;
•delay or increased costs to obtain right-of-way or other property rights;
•delays or failures by third parties to complete related projects;
•protests and other activist interference with planned or in-process projects;
•unplanned increases in the cost of construction materials or labor;
•shortages or disruptions in transportation of modular components and/or construction materials; or
•shortages of sufficiently skilled labor, or labor disagreements resulting in unplanned work stoppages.
Competing midstream service providers, including certain major energy and chemical companies, possess, or have greater financial resources to acquire, assets better suited to meet customer demand, which could undermine our ability to obtain and retain customers or reduce utilization of our assets, which could reduce our revenues and cash flows, thereby reducing our ability to make our quarterly distributions to unitholders.
We face competition in all aspects of our business and can give no assurances that we will be able to compete effectively against our competitors. Our competitors include major energy and chemical companies, some of which have greater financial resources, more pipelines or storage terminals, greater capacity pipelines or storage terminals and greater access to supply than we do. Certain of our competitors also have advantages in competing for acquisitions or other new business opportunities because of their financial resources and synergies in operations. As a consequence of increased competition in the industry or market conditions, some customers are and others may be in the future reluctant to renew or enter into long-term contracts or contracts that provide for minimum throughput amounts. Our inability to renew or replace a significant portion of our current contracts as they expire, to enter into contracts for newly acquired, constructed or expanded assets and to respond appropriately to changing market conditions would have a negative effect on our revenue, cash flows and ability to make quarterly distributions to our unitholders.
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Our operations are subject to operational hazards and interruptions, and we cannot insure against or predict all potential losses and liabilities that might result therefrom.
Our operations and those of our customers and suppliers are subject to operational hazards and unforeseen interruptions due to natural disasters, adverse weather conditions (such as hurricanes, tornadoes, storms, floods and earthquakes), accidents, fires, explosions, hazardous materials releases, mechanical failures, cyberattacks, acts of terrorism and other events beyond our control. These events have, and may in the future, result in a loss of life or equipment, injury or extensive property or environmental damage, as well as an interruption in our operations or those of our customers or suppliers. In the event any of our facilities, or those of our customers or suppliers, suffer significant damage or are forced to shut down for a significant period of time, it may have a material adverse effect on our results of operations and our financial condition as a whole. Additionally, our pipelines, terminals and storage assets are generally long-lived assets, and some have been in service for many years. The age and condition of our assets could result in increased maintenance or repair expenditures in the future.
As a result of market conditions and losses experienced by us and other companies, the premiums and deductibles for our insurance policies have increased and could continue to increase substantially; therefore, it has become increasingly difficult to, and we may not be able to, maintain or obtain insurance of the type and amount we desire at reasonable rates. In addition, certain insurance coverage is subject to broad exclusions, and may become subject to further exclusions, become unavailable altogether or become available only for reduced amounts of coverage and at higher rates. We are not fully insured against all hazards and risks to our business, and the insurance we carry requires us to meet deductibles before we collect for losses we sustain. If we incur a significant liability for which we are uninsured or not fully insured, or if there is a significant delay in payment of a major insurance claim, such a liability could have a material adverse effect on our financial position.
We are exposed to counterparty credit risk. Nonpayment and nonperformance by our customers, vendors or other counterparties reduces our revenues and increases our expenses, and any significant level of nonpayment and nonperformance could have a negative impact on our ability to conduct our business, operating results, cash flows and our ability to service our debt obligations and make distributions to our unitholders.
Weak and volatile economic conditions and widespread financial stress reduce the liquidity of our customers, vendors or other counterparties, making it more difficult for them to meet their obligations to us. We are therefore subject to risks of loss resulting from nonpayment or nonperformance by our customers to whom we extend credit. Financial problems encountered by our customers limit our ability to collect amounts owed to us, or to enforce the performance of obligations owed to us under contractual arrangements. In addition, nonperformance by vendors or their subcontractors, who have committed to provide us with critical products or services, increases our costs and could result in significant disruptions or interfere with our ability to successfully conduct our business. Although we attempt to mitigate our risk through warehouseman’s liens and other security protections, we are not always able to enforce such liens and protections due to competing claims from other parties. Any substantial increase in the nonpayment and nonperformance by our customers, vendors or other counterparties or our inability to enforce our warehouseman’s liens and other security protections could have a material adverse effect on our results of operations, cash flows and ability to make distributions to our unitholders.
We rely on our information technology and operational technology systems to conduct our business. Any significant cybersecurity breach or other significant disruption to those systems would cause our business, financial results and reputation to suffer, increase our costs and expose us to liability, and could adversely affect our ability to make distributions to our unitholders.
We rely on our information technology systems and our operational technology systems to process, transmit and store information, such as employee, customer and vendor data, and to conduct almost all aspects of our business, including safely operating our pipelines and storage facilities, recording and reporting commercial and financial transactions and receiving and making payments. We also rely on systems hosted by third parties, with respect to which we have limited visibility and control, and that have access to or store certain of our employee, customer and vendor data. The security of these networks and systems is critical to our operations and business strategy.
Although we take proactive steps to protect us, our systems and our data from cyberattacks, such as implementing multiple layers of security, segregated systems and user access, antivirus tools, vulnerability scanning, monitoring and patch management, regular employee training, phishing tests, penetration tests, internal risk assessments, independent third-party assessments, tabletop exercises to test our incident response plan, enhanced cyber diligence of vendors and physical security measures, all companies are at risk of a cyberattack. The number and sophistication of reported cyberattacks by both state-sponsored and criminal organizations continue to increase, across industries and around the world, including attacks on operators of critical infrastructure assets, such as pipelines, as well as the third parties that provide technology services for critical infrastructure, in some cases with considerable negative impact on targeted companies’ ability to conduct business.
Like other companies, we recognize that, despite our security measures, we remain subject to cybersecurity incidents due to attacks from a variety of external threat actors, internal employee error or malfeasance and cybersecurity incidents suffered by our service providers, vendors or customers. In addition, in connection with COVID-19 precautions, many of our employees and those of our service providers, vendors and customers have been working, and some may continue to work, from home or other remote-work locations, where cybersecurity protections may be less robust and cybersecurity procedures and safeguards may be less effective. Moreover, certain attacker techniques and goals, such as surveillance, intelligence gathering or extended
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reconnaissance, may remain undetected for an extended period of time, which can increase the breadth and negative impact of an incident. A significant failure, compromise, breach or interruption in our systems or those of third parties critical to our operations could result in a disruption of our operations; physical damage to our assets or the environment; physical, financial, or other harm to employees or others; safety incidents; damage to our reputation; loss of customers or revenues; increased costs for remedial actions; and potential litigation or regulatory fines. Failures, interruptions and similar events that result in the loss or improper disclosure of information maintained in our systems and networks or those of our vendors, including personnel, customer and vendor information, have in the past and may in the future require reporting under relevant contractual obligations and laws and regulations protecting personal data and privacy and could also subject us to litigation or other liability under relevant contractual obligations, laws and regulations. Our financial results could also be adversely affected if our systems are breached or an employee, vendor or customer causes our systems to fail, either as a result of inadvertent error or deliberate tampering with or manipulation of our systems.
Due to the continued acceleration of cyberattacks, generally and against our industry, regulatory actions by federal, state and local governmental agencies in the United States and in other countries in which we operate have increased. Evolving laws and regulations governing cybersecurity and data privacy and protection pose increasingly complex compliance challenges. Although we believe that we have robust cybersecurity procedures and other safeguards in place, we cannot guarantee their effectiveness, and a significant failure, compromise, breach or interruption in our systems or those of our customers or vendors could have a material effect on our operations and the operations of our customers and vendors. As threats continue to evolve and cybersecurity and data privacy and protection laws and regulations continue to develop, we have spent and expect to continue spending additional resources to continue to enhance our cybersecurity, data protection, business continuity and incident response measures, to investigate and remediate any vulnerabilities to, or consequences of, cyber incidents, as well as on regulatory compliance.
Disputes regarding a failure to maintain product quality specifications or other claims related to the operation of our assets and the services we provide to our customers result in unforeseen expenses and could result in the loss of customers.
Certain of the products we store and transport are produced to precise customer specifications. If the quality and purity of the products we receive are not maintained or a product fails to perform in a manner consistent with the quality specifications required by our customers, customers have sought, and could in the future seek, replacement of the product or damages for costs incurred as a result of the product failing to perform as guaranteed. We also have faced, and could in the future face, other claims by our customers if our assets do not operate as expected by our customers or our services otherwise do not meet our customers’ expectations. Successful claims or a series of claims against us result in unforeseen expenditures and could result in the loss of one or more customers.
Climate change and fuels legislation and other regulatory initiatives restricting emissions of “greenhouse gases” may decrease demand for some of the products we store, transport and sell, increase our operating costs or reduce our ability to expand our facilities.
Federal and state legislative and regulatory initiatives in the United States, as well as international efforts, have attempted to and will continue to address climate change and control or limit emissions of greenhouse gases. For example, the United States is now a party to the Paris Agreement and has established an economy-wide target of reducing its net greenhouse gas emissions by 50-52 percent below 2005 levels in 2030 and achieving net zero greenhouse gas emissions economy-wide by no later than 2050. The United States has also established a goal to reach 100 percent carbon emissions-free electricity by 2035. Furthermore, many state and local leaders have stated their intent to increase efforts to control or limit emissions of greenhouse gases. To this end, climate change laws or regulations enacted by the United States and other political bodies that increase costs, reduce demand or otherwise impede our operations, could, directly or indirectly, have an adverse direct or indirect effect on our business. Specifically, certain regulatory changes have and future changes could restrict our ability to expand our operations and increase our costs to operate and maintain our existing facilities by requiring that we measure and report our emissions, install new emission controls on our facilities, acquire allowances to authorize our emissions, pay taxes related to our emissions or administer and manage an emissions program, among other things. The passage of climate change legislation and interpretation and action of federal and state regulatory bodies that result in a reduction in the demand for hydrocarbon products that are deemed to contribute to greenhouse gases, or restrictions on their use, may reduce volumes available to us for transportation and storage. These developments could have adverse effects on our business, financial position, results of operations and prospects.
In addition, certain of our blending operations subject us to potential requirements to purchase renewable fuels credits. Even though we attempt to mitigate such lost revenues or increased costs through the contracts we sign with our customers, we sometimes are not able to recover those revenues or mitigate the increased costs, and any such recovery depends on events beyond our control, including the outcome of future rate proceedings before the Federal Energy Regulatory Commission (FERC) or other regulators and the provisions of any final legislation or regulations. Reductions in our revenues or increases in our expenses as a result of climate change legislation or other regulatory initiatives could have adverse effects on our business, financial position, results of operations and prospects.
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Finally, increasing concentrations of greenhouse gases in the Earth’s atmosphere may produce climate changes that have significant physical effects, such as increased frequency and severity of storms, floods and other climatic events. Such events have had and may in the future have an adverse effect on our assets and operations, especially those located in coastal regions.
Public sentiment towards climate change, fossil fuels and sustainability could adversely affect our business, operations and ability to attract capital.
Our business plans are based upon the assumption that public sentiment and the regulatory environment will continue to enable the future development, transportation and use of carbon-based fuels. Negative public perception of the industry in which we operate and the influence of environmental activists and initiatives aimed at limiting climate change could interfere with our business activities, operations and access to capital. Activists concerned about the potential effects of climate change have directed their attention towards sources of funding for fossil fuel energy companies, which has resulted in certain financial institutions, funds and other sources of capital reducing or ceasing lending to or investing in companies in the fossil fuel energy industry, such as us. Such negative sentiment regarding our industry could influence consumer preference and decrease demand for the products we transport and store and result in increased regulatory scrutiny, which could then result in additional laws, regulations, guidelines and enforcement interpretations, at the federal, state or local level. These actions may cause operational delays or restrictions, increased operating costs, additional regulatory burdens and increased risk of litigation.
Members of the investment community are also increasing their focus on sustainability practices, including practices related to greenhouse gas emissions and climate change, in the energy industry. Additionally, some members of the investment community screen companies such as ours for sustainability performance before investing in our units. In response to the increasing pressure regarding sustainability disclosures and practices, we and other companies in our industries publish sustainability reports that are made available to investors. Such reports are used by some investors to inform their investment and voting decisions, and we may continue to face increasing pressure regarding sustainability practices and disclosures. Unfavorable sustainability ratings by organizations that provide such information to investors may lead to increased negative investor sentiment toward us or our customers and to the diversion of investment to other industries, which would have a negative impact on our unit price and/or our access to and costs of capital.
Our operations are subject to federal, state and local laws and regulations, in the U.S. and in the other countries in which we operate, relating to environmental, health, safety and security that require us to make substantial expenditures.
Our operations are subject to increasingly stringent international, federal, state and local environmental, health, safety and security laws and regulations. Transporting, storing and distributing hazardous materials, including petroleum products, entails the risk of releasing these products into the environment, potentially causing substantial expenditures for a response action, significant government penalties, liability to government agencies including for damages to natural resources, personal injury or property damages to private parties and significant business interruption. Further, our pipeline facilities are subject to the pipeline integrity and safety regulations of various federal and state regulatory agencies, as well as cybersecurity directives. In recent years, increased regulatory focus on pipeline integrity, safety and security has resulted in various proposed or adopted regulations. The implementation of these regulations has required, and the adoption of future regulations could require, us to make additional capital or other expenditures, including to install new or modified safety or security measures, or to conduct new or more extensive inspection and maintenance programs.
Legislative action and regulatory initiatives have resulted in, and could in the future result in, changes to operating permits, material changes in operations, increased capital expenditures and operating costs, increased costs of the goods we transport and/or decreased demand for products we handle. Future impacts cannot be assessed with certainty at this time. Required expenditures to modify operations or install pollution control equipment or release prevention and containment systems or other environmental, health, safety or security measures could materially and adversely affect our business, financial condition, results of operations and liquidity if these expenditures, as with all costs, are not ultimately reflected in the tariffs and other fees we receive for our services.
We own or lease a number of properties that were used to transport, store or distribute products for many years before we acquired them; therefore, such properties were operated by third parties whose handling, disposal or release of products and wastes was not under our control. Environmental laws and regulations could impose obligations to conduct assessment or remediation efforts at our facilities, third-party sites where we take wastes for disposal, or where wastes have migrated. Environmental laws and regulations also impose joint and several liability on us for the conduct of third parties or for actions that complied with applicable requirements when taken, regardless of negligence or fault. If we were to incur a significant liability pursuant to environmental, health, safety or security laws or regulations, such a liability could have a material adverse effect on our financial position.
We operate assets outside of the United States, which exposes us to different legal and regulatory requirements and additional risk.
A portion of our revenues are generated from our assets located in Canada and northern Mexico. Our operations in both locations are subject to various risks unique to each country in which we operate that could have a material adverse effect on our business, results of operations and financial condition. With respect to any particular country, these risks may include political and economic instability, including: civil unrest; labor strikes; war and other armed conflict; inflation; and currency
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fluctuations, devaluation and conversion restrictions. Any deterioration of social, political, labor or economic conditions, including the increasing threat of terrorist organizations and drug cartels, in a country or region in which we do business, or affecting a customer with whom we do business, as well as difficulties in staffing, obtaining necessary equipment and supplies and managing foreign operations, may adversely affect our operations or financial results. We are also exposed to the risk of foreign and domestic governmental actions that may: impose additional costs on us; delay permits or otherwise impede our operations; limit or disrupt markets for our operations, restrict payments or limit the movement of funds; impose sanctions on or otherwise restrict our ability to conduct business with certain customers or persons or in certain countries; or result in the deprivation of contract rights. Our operations outside the United States may also be affected by changes in trade protection laws, policies and measures, and other regulatory requirements affecting trade and investment, including the Foreign Corrupt Practices Act and foreign laws prohibiting corrupt payments, as well as travel restrictions and import and export regulations.
We may be unable to obtain or renew permits necessary for our current or proposed operations, which could inhibit our ability to conduct or expand our business.
Our facilities operate under a number of federal, state and local permits, licenses and approvals with terms and conditions containing a significant number of prescriptive limits and performance standards in order to operate. These limits and standards require a significant amount of monitoring, recordkeeping and reporting in order to demonstrate compliance with the underlying permit, license or approval. Noncompliance or incomplete documentation of our compliance status may result in the imposition of fines, penalties and injunctive relief. In addition, public protest, political activism and responsive government intervention have made it more difficult for energy companies to acquire the permits required to complete planned infrastructure projects. A decision by a government agency to deny or delay issuing a new or renewed permit, license or approval, or to revoke or substantially modify an existing permit, license or approval, could have a material adverse effect on our ability to continue or expand our operations and on our financial condition, results of operations, cash flows and ability to make distributions to our unitholders.
We could be subject to liabilities from our assets that predate our acquisition of those assets, but that are not covered by indemnification rights we have against the sellers of the assets.
We have acquired assets and businesses and we are not always indemnified by the seller for liabilities that precede our ownership. In addition, in some cases, we have indemnified the previous owners and operators of acquired assets or businesses. Some of our assets have been used for many years to transport and store crude oil and refined products, and past releases could require costly future remediation. If a significant release or event occurred in the past, the liability for which was not retained by the seller, or for which indemnification by the seller is not available, it could adversely affect our financial position and results of operations. Conversely, if liabilities arise from assets we have sold, we could incur costs related to those liabilities if the buyer possesses valid indemnification rights against us with respect to those assets.
Our interstate common carrier pipelines are subject to regulation by the FERC, which could have an adverse impact on our ability to recover the full cost of operating our pipelines and the revenue we are able to receive from those operations.
The FERC regulates the tariff rates and terms and conditions of service for interstate oil movements on common carrier pipelines. FERC requires that these rates be just and reasonable and that the pipeline not engage in undue discrimination with respect to any shipper. The FERC or shippers may challenge required pipeline tariff filings, including rates and terms and conditions of service. Further, other than for rates set under market-based rate authority, if a new rate is challenged by protest and investigated by the FERC, the FERC may require the pipeline owner to refund amounts collected in excess of the deemed just and reasonable rate. In addition, shippers may challenge by complaint tariff rates and terms and conditions of service even after they take effect, and the FERC may order a carrier to change its rates prospectively to a just and reasonable level. A complaining shipper also may obtain reparations for damages sustained during the two years prior to the date of the complaint.
We are able to use various FERC-authorized rate change methodologies for our interstate pipelines, including indexed rates, cost-of-service rates, market-based rates and negotiated rates. Typically, we adjust our rates annually in accordance with the FERC indexing methodology, which currently allows a pipeline to change its rates within prescribed ceiling levels that are tied to an inflation index. It is possible that the index may result in negative rate adjustments in some years, or that changes in the index might not be large enough to fully reflect actual increases in our costs. The FERC’s indexing methodology is subject to review and revision every five years, with the most recent five-year review occurring in 2020. On December 17, 2020, the FERC established the index level for the five-year period commencing July 1, 2021, which will end on June 30, 2026, at the Bureau of Labor’s producer price index for finished goods (PPI-FG) plus 0.78%. On January 20, 2022, the FERC granted rehearing of certain aspects of the final rule and revised the index level to PPI-FG minus 0.21%, effective March 1, 2022 through June 30, 2026. FERC ordered pipelines with filed rates that exceed their index ceiling levels based on PPI-FG minus 0.21% to file rate reductions effective March 1, 2022. Subsequent appellate review could result in a further change to the index.
FERC has granted us authority to charge market-based rates on some of our pipelines, which are not subject to cost-of-service or indexing constraints. If we were to lose market-based rate authority, however, we could be required to establish rates on some other basis, such as cost-of-service, which could reduce our revenues and cash flows. Additionally, because competition constrains our rates in various markets, we may from time to time be forced to reduce some of our rates to remain competitive.
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We do not own all of the land on which our pipelines and facilities are located, and we are therefore subject to the possibility of increased costs or the inability to retain necessary land use.
Like other pipeline and storage logistics services providers, certain of our pipelines, storage terminals and other facilities are located on land owned by third parties and governmental agencies that we have obtained the right to utilize for these purposes through contract (rather than through outright purchase). Many of our rights-of-way or other property rights are perpetual in duration, but others are for a specific period of time. In addition, some of our facilities are located on leased premises. A potential loss of property rights through our inability to renew right-of-way contracts or leases or otherwise retain property rights on acceptable terms or the increased costs to renew such rights could adversely affect our financial condition, results of operations and cash flows available for distribution to our unitholders.
Increases in power prices could adversely affect our operating expenses and our ability to make distributions to our unitholders.
Power costs constitute a significant portion of our operating expenses. For the year ended December 31, 2021, our power costs equaled approximately $46.4 million, or 12% of our operating expenses for the year. We use mainly electric power at our pipeline pump stations and terminals, and such electric power is furnished by various utility companies. Requirements for utilities to use less carbon intensive power or to add pollution control devices also could cause our power costs to increase and our cash flows may be adversely affected, which could adversely affect our ability to make distributions to our unitholders.
We may be adversely affected by changes in the method of determining the London Interbank Offering Rate (LIBOR) or the replacement of LIBOR with an alternative reference rate.
The publication of non-U.S. dollar LIBOR rates ceased after publication on December 31, 2021 and the publication of U.S. dollar LIBOR rates for the most common tenors (overnight and one, three, six and twelve months) is expected to cease after publication on June 30, 2023. Regulators have emphasized that, despite any continued publication of U.S. dollar LIBOR rates through June 30, 2023, no new contracts using U.S. dollar LIBOR rates should be entered into after December 31, 2021. Accordingly, the transition away from the widespread use of LIBOR to alternative rates has begun and is expected to continue over the next couple of years. Further, there is no assurance that LIBOR, or any particular currency and tenor, will continue to be published until any particular date.
Following the amendment and restatement of our revolving credit agreement and the amendment of our accounts receivable securitization program on January 28, 2022, we had approximately $0.4 billion of variable-rate indebtedness using LIBOR as a benchmark for establishing the interest rate. In addition, the distribution rates on our Series A preferred units converted from a fixed rate to a floating rate based on LIBOR in December 2021, with our Series B and C preferred units scheduled to convert to a floating rate based on LIBOR in June 2022 and December 2022, respectively. Although our variable rate indebtedness and Series A, B and C preferred units contain certain alternative calculation measures if LIBOR is no longer published, we are unable to unilaterally change the LIBOR-based rates on our variable rate indebtedness and Series A, B and C preferred units to a replacement benchmark rate without the consent of the holders of the variable rate indebtedness, the holders of 66-2/3% of each of the Series A and Series B preferred units and the calculation agent for the Series C preferred units, and we may not be able to do so on terms favorable to us. The consequences of the transition away from LIBOR cannot be entirely predicted but could include an increase in the cost of our variable-rate indebtedness, our Series A, B and C preferred units and other commercial arrangements tied to LIBOR. Furthermore, uncertainty regarding the continued use and reliability of LIBOR as a benchmark rate and uncertainty regarding its replacement could disrupt the financial markets or adversely affect the value of our arrangements tied to LIBOR.
An impairment of goodwill or long-lived assets could reduce our earnings.
As of December 31, 2021, we had $0.7 billion of goodwill and $4.1 billion of long-lived assets, including property, plant and equipment, net and intangible assets, net. U.S. generally accepted accounting principles requires us to test both goodwill and long-lived assets for impairment when events or circumstances occur indicating that either goodwill or long-lived assets might be impaired and, in the case of goodwill, at least annually. Charges to impair our goodwill or our long-lived assets reduce earnings and partners’ capital. Any event that causes a reduction in demand for our services could result in a reduction of our estimates of future cash flows and growth rates in our business, which could cause us to record an impairment charge to reduce the value of goodwill. Similarly, any event or change in circumstances that causes the carrying value of our long-lived assets to no longer be recoverable may require us to record an impairment charge to reduce the value of our long-lived assets.
If we determine that either our goodwill or our long-lived assets are impaired, the resulting charge will reduce earnings and partners’ capital. For example, in October 2021, we sold our Eastern U.S. Terminal Operations, and in the third quarter of 2021, we recorded long-lived asset and goodwill impairment charges related to the sale of $95.7 million and $34.1 million, respectively. We also recorded a long-lived asset impairment charge of $59.2 million during the third quarter of 2021 related to a section of a refined products pipeline that would require significant investment in order to pursue commercial opportunities.
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RISKS INHERENT IN AN INVESTMENT IN US
As a master limited partnership, we do not have the same flexibility that corporations and other types of organizations may have to accumulate cash and prevent illiquidity in the future, which may also limit our growth.
Unlike a corporation, our partnership agreement requires us to make quarterly distributions to our common unitholders of all available cash, after taking into account reserves for commitments and contingencies, including growth and other capital expenditures and operating costs, debt service requirements and payments with respect to our preferred units. We are therefore more likely than those organizations to require issuances of additional debt and equity securities to finance our growth plans, meet unforeseen cash requirements and service our debt and other obligations.
In addition, to the extent we issue additional units in connection with any acquisitions or growth capital expenditures, the payment of distributions on those additional units may increase the risk that we will be unable to maintain our current per unit distribution level and the value of our common units and other limited partner interests may decrease in correlation with any reduction in our cash distributions per unit. Accordingly, if we experience a liquidity shortage in the future, we may not be able to issue more equity to recapitalize.
Unitholders have limited voting rights, and our partnership agreement restricts the voting rights of certain unitholders owning 20% or more of any class of our units.
Unlike holders of common stock in a corporation, unitholders have only limited voting rights on matters affecting our business and, therefore, limited ability to influence management’s decisions regarding our business. Unitholders’ voting rights are further restricted by a provision in our partnership agreement providing that units held by certain persons that own 20% or more of any class of units then outstanding cannot vote on any matter without the prior approval of our general partner.
We may issue additional equity securities, including equity securities that are senior to our common units, which would dilute our unitholders’ existing ownership interests.
Our partnership agreement allows us to issue an unlimited number of additional equity securities without the approval of other unitholders as long as the newly issued equity securities are not senior to, or equally ranked with, our preferred units. With the consent of the holders of a majority of the Series D Preferred Units, we may issue an unlimited number of units that are senior to our common units and equally ranked with our preferred units. However, in certain circumstances, we may be required to obtain the approval of the holders of a majority of each class of our preferred units before we could issue equity securities that are equally ranked with our preferred units.
Our issuance of additional units or other equity interests of equal or senior rank will have the following effects:
•our unitholders’ proportionate ownership interest in us will decrease;
•the amount of cash available for distribution on each unit may decrease;
•the amount of cash available for redemption of, or payment of the liquidation preference on, each preferred unit may decrease;
•the ratio of taxable income to distributions may increase;
•the relative voting strength of each previously outstanding unit may be diminished; and
•the market price of our common units and preferred units may decline.
Holders of our Series D Preferred Units generally have the same voting rights as holders of our common units and generally vote on an as-converted basis with the holders of our common units as a single class. Although holders of our other preferred units also have voting rights, such rights are limited to certain matters and require that such holders vote as a separate class with all other series of our equally ranked securities that may be issued and possess similar voting rights. As a result, the voting rights of holders of our preferred units may be significantly diluted, and the holders of such future securities of equal rank may be able to control or significantly influence the outcome of any vote with respect to which the holders of our preferred units are entitled to vote. Our partnership agreement contains limited protections for the holders of our preferred units (other than Series D Preferred Units) in the event of a transaction, including a merger, sale, lease or conveyance of all or substantially all of our assets or business, which might adversely affect the holders of our preferred units.
Future issuances and sales of securities that rank equally with our preferred units, or the perception that such issuances and sales could occur, may cause prevailing market prices for our preferred units and our common units to decline and may adversely affect our ability to raise additional capital in the financial markets at times and prices favorable to us. Furthermore, the payment of distributions on any additional units may increase the risk that we will not be able to make distributions at our prior per unit distribution levels. To the extent new units are senior to our common units, their issuance will increase the uncertainty of the payment of distributions on our common units.
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If we do not pay distributions on our preferred units in any distribution period, we would be unable to declare or pay distributions on our common units until all unpaid preferred unit distribution obligations have been paid, and our common unitholders are not entitled to receive distributions for such prior period.
Our preferred units rank senior to our common units with respect to distribution rights and rights upon liquidation. If we do not pay the required distributions on our preferred units, we will be unable to declare or pay distributions on our common units. Additionally, because distributions to our preferred unitholders are cumulative, we will have to pay all unpaid accumulated preferred distributions before we can declare or pay any distributions to our common unitholders. Also, because distributions to our common unitholders are not cumulative, if we do not pay distributions on our common units with respect to any quarter, our common unitholders will not be entitled to receive distributions covering any prior periods. In addition, if we do not pay the required distributions on our Series D Preferred Units for three consecutive distribution periods, the holders of our Series D Preferred Units have certain additional rights until such distributions are paid, including the right to convert the Series D Preferred Units into common units, the right to appoint one director to our board of directors and the right to approve certain subsequent indebtedness, acquisitions or asset sales. The preferences and privileges of our preferred units could adversely affect the market price for our common units, or could make it more difficult for us to sell our common units in the future.
If a court were to determine that a unitholder action constituted control of our business, the unitholders may lose their legal protection from liability and be required to repay distributions wrongfully distributed to them.
Under Delaware law, if a court were to determine that actions of a unitholder constituted participation in the “control” of our business, unitholders would be held liable for our obligations to the same extent as a general partner. In addition, under Delaware law, the general partner generally has unlimited liability for the obligations of the partnership, such as its debts and environmental liabilities, except for those contractual obligations of the partnership that are expressly made without recourse to the general partner.
Furthermore, under Delaware law, we may not make a distribution to our unitholders if the distribution would cause our liabilities to exceed the fair value of our assets. Liabilities to partners on account of their partnership interests and liabilities that are nonrecourse to the partnership are not counted for purposes of determining whether a distribution is permitted. Delaware law provides that, for a period of three years from the date of an impermissible distribution, limited partners who received the distribution and who knew at the time of the distribution that it violated Delaware law will be liable to us for the repayment of the distribution amount. Likewise, upon the winding up of our partnership, in the event that (a) we do not distribute assets in the following order: (1) to creditors in satisfaction of our debts; (2) to partners and former partners in satisfaction of liabilities for distributions owed under our partnership agreement; (3) to partners for the return of their contributions; and finally (4) to the partners in the proportions in which the partners share in distributions and (b) a limited partner knows at the time that the distribution violated Delaware law, then such limited partner will be liable to repay the distribution for a period of three years from the impermissible distribution under applicable Delaware law.
A purchaser of our common or preferred units becomes a limited partner and is liable for the obligations of the transferring limited partner to make contributions to us that are known to such purchaser of common or preferred units at the time it became a limited partner and, for unknown obligations, if the liabilities could be determined from our partnership agreement.
The NYSE does not require a publicly traded limited partnership like us to comply with certain of its corporate governance requirements.
We currently list our common units on the NYSE under the symbol “NS” and certain of our preferred units on the NYSE under the symbols “NSprA,” “NSprB” and “NSprC,” respectively. Although our general partner has maintained a majority of independent directors on its board and all members of its board’s audit committee, compensation committee and nominating/governance & conflicts committee are independent directors, because we are a publicly traded limited partnership, the NYSE does not require us to have a majority of independent directors on our general partner’s board of directors or to have a compensation committee or a nominating committee consisting of independent directors. Additionally, any future issuance of additional common or preferred units or other securities, including to affiliates, will not be subject to the NYSE’s shareholder approval rules that apply to a corporation. Accordingly, the NYSE does not mandate the same protections for our unitholders as are required for certain corporations that are subject to all of the NYSE corporate governance requirements.
TAX RISKS TO OUR UNITHOLDERS
If we were treated as a corporation for federal or state income tax purposes or we were otherwise subject to a material amount of entity-level taxation, then our cash available for distribution to unitholders would be substantially reduced.
The anticipated after-tax benefit of an investment in our units depends largely on our being treated as a partnership for federal income tax purposes. Despite the fact that we are a limited partnership under Delaware law, we will be treated as a corporation for federal income tax purposes unless we satisfy a “qualifying income” requirement. Based upon our current operations, we believe we satisfy the qualifying income requirement.
If we were treated as a corporation, we would pay federal income tax at the corporate tax rate and would likely pay state and local income tax at varying rates. Distributions to unitholders would generally be taxed again as corporate distributions, and no income, gains, losses, deductions or credits would flow through to unitholders. Because a tax would be imposed upon us as a
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corporation, our distributable cash flow would be substantially reduced. Additionally, at the state level, several states are evaluating ways to subject partnerships to entity-level taxation through the imposition of state income, franchise and other forms of taxation. If we were treated as a corporation for federal income tax purposes or otherwise subjected to a material amount of entity-level taxation, then our cash available for distribution to unitholders would be substantially reduced and there would be a material reduction in the after-tax return to our unitholders, likely causing a substantial reduction in the value of our units.
The tax treatment of publicly traded partnerships or an investment in our units could be subject to potential legislative, judicial or administrative changes or differing interpretations, possibly applied on a retroactive basis.
The present U.S. federal income tax treatment of publicly traded partnerships, including us, or an investment in our units may be modified by administrative, legislative or judicial changes or differing interpretations at any time. From time to time, members of Congress propose and consider such substantive changes to the existing federal income tax laws that affect publicly traded partnerships, including elimination of partnership tax treatment for certain publicly traded partnerships.
Any changes to the federal income tax laws and interpretations thereof may be applied retroactively and could make it more difficult or impossible for us to meet the exception for certain publicly traded partnerships to be treated as partnerships for federal income tax purposes or otherwise adversely affect our business, financial condition or results of operations. We are unable to predict whether any additional changes or other proposals will ultimately be enacted. Any such changes could negatively impact the value of an investment in our units.
If the IRS makes audit adjustments to our income tax returns for tax years beginning after December 31, 2017, it (and some states) may assess and collect any taxes, penalties and interest directly from us. If we bear such payment, our cash available for distribution to our unitholders might be substantially reduced.
For tax years beginning after December 31, 2017, if the IRS makes audit adjustments to our income tax returns, it (and some states) may assess and collect any taxes, penalties and interest resulting from such audit adjustment directly from us. To the extent possible under applicable rules, our general partner may pay such amounts directly to the IRS or, if we are eligible, elect to issue a revised Schedule K-1 to each unitholder with respect to an audited and adjusted return. No assurances can be made that such election will be practical, permissible or effective in all circumstances. As a result, our current unitholders may bear some or all of the tax liability resulting from such audit adjustment, even if such unitholders did not own common units in us during the tax year under audit. If, as a result of any such audit adjustment, we make payments of taxes, penalties and interest, our cash available for distribution to our unitholders could be substantially reduced.
Unitholders will be required to pay taxes on their share of our taxable income even if they do not receive cash distributions from us.
Unitholders will be required to pay federal income taxes and, in some cases, state and local income taxes on their respective share of our taxable income, whether or not the unitholders receive cash distributions from us. Unitholders may not receive cash distributions from us equal to their respective share of our taxable income or even equal to the actual tax liability that results from their share of our taxable income.
Tax gain or loss on the disposition of our units could be different than expected.
A unitholder who sells units will recognize a gain or loss equal to the difference between the amount realized and the unitholder’s tax basis in those units. Prior distributions to the unitholder in excess of the total net taxable income with respect to a unit will reduce the unitholder’s tax basis in that unit. As a result, the selling unitholder can recognize a gain if such unit is sold at a price greater than the unitholder’s tax basis in that unit, even if the price the unitholder receives is less than the unit’s original cost. A substantial portion of the amount realized, even if there is a net taxable loss realized on the sale, may be ordinary income to the selling unitholder.
Unitholders may be subject to limitations on their ability to deduct interest expense incurred by us.
Our ability to deduct interest paid or accrued on indebtedness properly allocable to a trade or business, “business interest”, may be limited in certain circumstances. Should our ability to deduct business interest be limited, the amount of taxable income allocated to our unitholders in the taxable year in which the limitation is in effect may increase. However, in certain circumstances, a unitholder may be able to utilize a portion of a business interest deduction subject to this limitation in future taxable years. Prospective unitholders should consult their tax advisors regarding the impact of this business interest deduction limitation on an investment in our units.
Tax-exempt entities face unique tax issues from owning our units that may result in adverse tax consequences to them.
Investment in our units by tax-exempt entities, such as employee benefit plans and individual retirement accounts (IRAs) raises issues unique to them. For example, virtually all of our income allocated to organizations that are exempt from U.S. federal income tax, including IRAs and other retirement plans, will be unrelated business taxable income and will be taxable to them. Tax-exempt entities should consult a tax advisor before investing in our units.
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Non-U.S. unitholders will be subject to U.S. taxes and withholding with respect to their income and gain from owning our units.
Non-U.S. unitholders are subject to U.S. federal income tax on income effectively connected with a U.S. trade or business (effectively connected income). A unitholder’s share of our income, gain, loss and deduction, and any gain from the sale or disposition of our units will generally be considered to be effectively connected income and subject to U.S. federal income tax. Additionally, distributions to a non-U.S. unitholder will be subject to withholding at the highest applicable effective tax rate.
Moreover, the transferee of an interest in a partnership that is engaged in a U.S. trade or business is generally required to withhold 10% of the amount realized by the transferor unless the transferor certifies that it is not a foreign person. Treasury regulations provide that the “amount realized” on a transfer of an interest in a publicly traded partnership will generally be the amount of gross proceeds paid to the broker effecting the applicable transfer on behalf of the transferor. The Treasury regulations further provide that withholding on a transfer of an interest in a publicly traded partnership will not be imposed on a transfer that occurs prior to January 1, 2022, and after that date, if effected through a broker, the obligation to withhold is imposed on the transferor’s broker. Non-U.S. unitholders should consult a tax advisor before investing in our units.
We will treat each purchaser of our common units as having the same tax benefits without regard to the units purchased. The IRS may challenge this treatment, which could adversely affect the value of our common units.
Because we cannot match transferors and transferees of our common units, we have adopted depreciation and amortization positions that may not conform with all aspects of existing Treasury regulations. A successful IRS challenge to those positions could adversely affect the amount of tax benefits available to unitholders. It also could affect the timing of these tax benefits or the amount of gain from a unitholder’s sale of common units and could have a negative impact on the value of our common units or result in audit adjustments to the unitholder’s tax returns.
Unitholders will likely be subject to state and local taxes and return filing requirements as a result of investing in our units.
In addition to federal income taxes, unitholders will likely be subject to other taxes, such as state and local income taxes, unincorporated business taxes and estate, inheritance or intangible taxes that are imposed by the various jurisdictions in which we do business or own property. Unitholders will likely be required to file state and local income tax returns and pay state and local income taxes in some or all of these various jurisdictions. Further, unitholders may be subject to penalties for failure to comply with those requirements. We may own property or conduct business in other states or foreign countries in the future. It is each unitholder’s responsibility to file all federal, state and local tax returns.
We prorate our items of income, gain, loss and deduction between transferors and transferees of our common units each month based upon the ownership of our common units on the first day of each month, instead of on the basis of the date a particular common unit is transferred. The IRS may challenge this treatment, which could change the allocation of items of income, gain, loss and deduction among our common unitholders.
We prorate our items of income, gain, loss and deduction between transferors and transferees of our common units each month based upon the ownership of our common units on the first day of each month, instead of on the basis of the date a particular common unit is transferred. Treasury regulations allow a similar monthly simplifying convention, but such regulations do not specifically authorize all aspects of our proration method. If the IRS were to challenge our proration method, we may be required to change the allocation of items of income, gain, loss and deduction among our common unitholders.
We have adopted certain valuation methodologies in determining a common unitholder’s allocations of income, gain, loss and deduction. The IRS may challenge these methods or the resulting allocations and such a challenge could adversely affect the value of our common units.
In determining the items of income, gain, loss and deduction allocable to our common unitholders, we must routinely determine the fair market value of our respective assets. Although we may from time to time consult with professional appraisers regarding valuation matters, we make fair market value estimates using a methodology based on the market value of our common units as a means to measure the fair market value of our respective assets. The IRS may challenge these valuation methods and the resulting allocations of income, gain, loss and deduction.
A successful IRS challenge to these methods or allocations could adversely affect the amount, character and timing of taxable income or loss being allocated to our common unitholders. It also could affect the amount of gain from our unitholders’ sale of common units and could have a negative impact on the value of the common units or result in audit adjustments to our common unitholders’ tax returns without the benefit of additional deductions.
A unitholder whose units are the subject of a securities loan (e.g., a loan to a “short seller”) may be considered as having disposed of those units. If so, the unitholder would no longer be treated for tax purposes as a partner with respect to those units during the period of the loan and may recognize gain or loss from the disposition.
Because there are no specific rules governing the federal income tax consequences of loaning a partnership interest, a unitholder whose units are the subject of a securities loan may be considered as having disposed of the loaned units. In that case, the unitholder may no longer be treated for tax purposes as a partner with respect to those units during the period of the loan and the unitholder may recognize gain or loss from such disposition. Moreover, during the period of the loan, any of our income,
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gain, loss or deduction with respect to those units may not be reportable by the unitholder and any cash distributions received by the unitholder as to those units could be fully taxable as ordinary income. Unitholders desiring to assure their status as partners and avoid the risk of gain recognition from a loan to a short seller are urged to consult a tax advisor to discuss whether it is advisable to modify any applicable brokerage account agreements to prohibit their brokers from borrowing their units.
Treatment of distributions on our preferred units as guaranteed payments for the use of capital creates a different tax treatment for the holders of preferred units than the holders of our common units and such distributions are not eligible for the 20% deduction for qualified publicly traded partnership income.
The tax treatment of distributions on our preferred units is uncertain. We will treat the holders of preferred units as partners for tax purposes and will treat distributions on the preferred units as guaranteed payments for the use of capital that will generally be taxable to the holders of preferred units as ordinary income. Holders of preferred units will recognize taxable income from the accrual of such a guaranteed payment even in the absence of a contemporaneous distribution. Otherwise, the holders of preferred units are generally not anticipated to share in our items of income, gain, loss or deduction, nor will we allocate any share of our nonrecourse liabilities to the holders of preferred units. If the preferred units were treated as indebtedness for tax purposes, rather than as guaranteed payments for the use of capital, distributions likely would be treated as payments of interest by us to the holders of preferred units.
Although we expect that much of our income will be eligible for the 20% deduction for qualified publicly traded partnership income, Treasury regulations provide that income attributable to a guaranteed payment for the use of capital is not eligible for the 20% deduction for qualified business income. As a result, income attributable to a guaranteed payment for use of capital recognized by holders of our preferred units is not eligible for the 20% deduction for qualified business income.
Investment in the preferred units by tax-exempt investors, such as employee benefit plans and IRAs, and non-U.S. persons raises issues unique to them. The treatment of guaranteed payments for the use of capital to tax-exempt investors is not certain and the income resulting from such payments may be treated as unrelated business taxable income for U.S. federal income tax purposes. A non-U.S. holder’s income from guaranteed payments and any gain from the sale or disposition of our units may be considered to be effectively connected income and subject to U.S. federal income tax. Distributions and any gain from the sale or disposition of our preferred units to non-U.S. holders of preferred units may be subject to withholding taxes. If the amount of withholding exceeds the amount of U.S. federal income tax actually due, non-U.S. holders of preferred units may be required to file U.S. federal income tax returns in order to seek a refund of such excess.
All holders of our preferred units are urged to consult a tax advisor with respect to the consequences of owning and selling our preferred units.
ITEM 1B. UNRESOLVED STAFF COMMENTS
None.
ITEM 3. LEGAL PROCEEDINGS
We are named as a defendant in litigation and are a party to other claims and legal proceedings relating to our normal business operations, including regulatory and environmental matters. Due to the inherent uncertainty of litigation, there can be no assurance that the resolution of any particular claim or proceeding would not have a material adverse effect on our results of operations, financial position or liquidity.
We are insured against various business risks to the extent we believe is prudent; however, we cannot assure you that the nature and amount of such insurance will be adequate, in every case, to protect us against liabilities arising from future legal proceedings from our business activity.
ITEM 4. MINE SAFETY DISCLOSURES
Not applicable.
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PART II
ITEM 5. MARKET FOR REGISTRANT’S COMMON UNITS, RELATED UNITHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES
Common Unit Distributions
Our common units are listed and traded on the New York Stock Exchange under the symbol “NS.” At the close of business on February 8, 2022, we had 370 holders of record of our common units. The following table presents the amount, record date and payment date of the quarterly cash distributions on our common units with respect to 2021 and 2020:
| Cash Distributions | |||||||||||||||||
| Amount Per Common Unit | Record Date | Payment Date | |||||||||||||||
| Year 2021 | |||||||||||||||||
| 4th Quarter | $ | 0.40 | February 8, 2022 | February 14, 2022 | |||||||||||||
| 3rd Quarter | $ | 0.40 | November 8, 2021 | November 12, 2021 | |||||||||||||
| 2nd Quarter | $ | 0.40 | August 6, 2021 | August 12, 2021 | |||||||||||||
| 1st Quarter | $ | 0.40 | May 10, 2021 | May 14, 2021 | |||||||||||||
| Year 2020 | |||||||||||||||||
| 4th Quarter | $ | 0.40 | February 8, 2021 | February 12, 2021 | |||||||||||||
| 3rd Quarter | $ | 0.40 | November 6, 2020 | November 13, 2020 | |||||||||||||
| 2nd Quarter | $ | 0.40 | August 7, 2020 | August 13, 2020 | |||||||||||||
| 1st Quarter | $ | 0.40 | May 11, 2020 | May 15, 2020 | |||||||||||||
Our partnership agreement requires that we distribute all “Available Cash” to our common limited partners each quarter. This term is defined in the partnership agreement generally as cash receipts less cash disbursements, including distributions to our preferred units, and cash reserves established by the general partner, in its sole discretion. See Item 7. “Management’s Discussion and Analysis of Financial Condition and Results of Operations” for further information regarding our distributions.
Preferred Unit Distributions
The following table provides the terms related to distributions for our Series A, B and C Preferred Units:
| Units | Fixed Distribution Rate Per Annum (as a Percentage of the $25.00 Liquidation Preference Per Unit) | Fixed Distribution Rate Per Unit Per Annum | Fixed Distribution Per Annum | Optional Redemption Date/Date at Which Distribution Rate Becomes Floating | Floating Annual Rate (as a Percentage of the $25.00 Liquidation Preference Per Unit) | |||||||||||||||||||||||||||
| (Thousands of Dollars) | ||||||||||||||||||||||||||||||||
| Series A Preferred Units | 8.50% | $ | 2.125 | $ | 19,252 | December 15, 2021 | Three-month LIBOR plus 6.766% | |||||||||||||||||||||||||
| Series B Preferred Units | 7.625% | $ | 1.90625 | $ | 29,357 | June 15, 2022 | Three-month LIBOR plus 5.643% | |||||||||||||||||||||||||
| Series C Preferred Units | 9.00% | $ | 2.25 | $ | 15,525 | December 15, 2022 | Three-month LIBOR plus 6.88% | |||||||||||||||||||||||||
The Series A Preferred Units switched from a fixed distribution rate to a floating rate on December 15, 2021, with the floating rate set forth below for the period indicated:
| Period | Distribution Rate per Unit | Total Distribution | ||||||||||||
| (Thousands of Dollars) | ||||||||||||||
| December 15, 2021 - March 14, 2022 | $ | 0.43606 | $ | 3,951 | ||||||||||
The distribution rates on our 23,246,650 Series D Preferred Units issued and outstanding are as follows: (i) 9.75%, or $57.6 million, per annum ($0.619 per unit per distribution period) for the first two years (beginning with the September 17, 2018 distribution); (ii) 10.75%, or $63.4 million, per annum ($0.682 per unit per distribution period) for years three through five; and (iii) the greater of 13.75%, or $81.1 million, per annum ($0.872 per unit per distribution period) or the distribution per common unit thereafter.
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Distributions on our preferred units are payable out of any legally available funds, accrue and are cumulative from the original issuance dates, and are payable on the 15th day (or the next business day) of each of March, June, September and December of each year to holders of record on the first business day of each payment month. The preferred units rank equal to each other and senior to all of our other classes of equity securities with respect to distribution rights and rights upon liquidation. Please see Notes 17 and 18 of the Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplementary Data” for additional information on distributions to our preferred unitholders.
Performance Graph
The following Performance Graph is not “soliciting material,” is not deemed filed with the SEC and is not to be incorporated by reference into any of NuStar Energy’s filings under the Securities Act of 1933 or the Securities Exchange Act of 1934, as amended, respectively. The stock or unit price performance included in this graph is not necessarily indicative of future stock or unit price performance.
The following graph compares the cumulative five-year total return provided to holders of NuStar Energy’s common units relative to the cumulative total returns of the S&P 500 index and the Alerian MLP index. An investment of $100 (with reinvestment of all dividends) is assumed to have been made in our common units and in each of the indexes on December 31, 2016, and its relative performance is tracked through December 31, 2021.
*$100 invested on December 31, 2016 in stock or index, including reinvestment of dividends.
| As of December 31, | |||||||||||||||||||||||||||||||||||
| 2016 | 2017 | 2018 | 2019 | 2020 | 2021 | ||||||||||||||||||||||||||||||
| NuStar Energy L.P. | 100.00 | 66.73 | 51.96 | 70.16 | 44.05 | 53.53 | |||||||||||||||||||||||||||||
| S&P 500 Index | 100.00 | 121.83 | 116.49 | 153.17 | 181.35 | 233.41 | |||||||||||||||||||||||||||||
| Alerian MLP Index | 100.00 | 93.48 | 81.87 | 87.24 | 62.21 | 87.20 | |||||||||||||||||||||||||||||
49
Sales of Unregistered Securities
During the fourth quarters of 2021, 2020 and 2019 and the first quarter of 2020, NuStar Energy issued an aggregate of 5,509 common units, 11,384 common units, 14,896 common units and nine common units, respectively, in reliance upon an exemption from the registration requirements of the Securities Act of 1933, as amended, pursuant to Section 4(a)(2) thereof, upon the vesting of outstanding awards under a long-term incentive plan.
During the fourth quarter of 2019, NuStar Energy issued 527,426 common units at a price of $28.44 per unit to William E. Greehey, Chairman of the Board of Directors of NuStar GP, LLC, in reliance upon an exemption from the registration requirements of the Securities Act of 1933, as amended, pursuant to Section 4(a)(2) thereof. We used the proceeds of $15.0 million from the sale of these units for general partnership purposes.
50
ITEM 6. RESERVED
ITEM 7A.QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
We manage our exposure to changing interest rates principally through the use of a combination of fixed-rate debt and variable-rate debt. Borrowings under our variable-rate debt expose us to increases in interest rates.
On January 28, 2022, we amended and restated our $1.0 billion unsecured revolving credit agreement to extend the maturity to April 27, 2025, replace the LIBOR-based interest rate and modify other terms. Also on January 28, 2022, we amended our $100.0 million receivables financing agreement to extend the scheduled termination date to January 31, 2025, replace the LIBOR-based interest rate and modify other terms. Please refer to Note 12 of the Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplementary Data” for more information.
On November 1, 2021, we repaid our $250.0 million of 4.75% senior notes due February 1, 2022. The following tables present principal cash flows and related weighted-average interest rates by expected maturity dates for our long-term debt, excluding finance leases:
| December 31, 2021 | |||||||||||||||||||||||||||||||||||||||||||||||
| Expected Maturity Dates | |||||||||||||||||||||||||||||||||||||||||||||||
| 2022 | 2023 | 2024 | 2025 | 2026 | There- after | Total | Fair Value | ||||||||||||||||||||||||||||||||||||||||
| (Thousands of Dollars, Except Interest Rates) | |||||||||||||||||||||||||||||||||||||||||||||||
| Fixed-rate debt | $ | — | $ | — | $ | — | $ | 600,000 | $ | 500,000 | $ | 1,472,140 | $ | 2,572,140 | $ | 2,858,794 | |||||||||||||||||||||||||||||||
| Weighted-average rate | — | — | — | 5.8 | % | 6.0 | % | 6.0 | % | 6.0 | % | — | |||||||||||||||||||||||||||||||||||
| Variable-rate debt | $ | — | $ | 194,300 | $ | — | $ | — | $ | — | $ | 402,500 | $ | 596,800 | $ | 600,359 | |||||||||||||||||||||||||||||||
| Weighted-average rate | — | 2.5 | % | — | — | — | 6.9 | % | 5.4 | % | — | ||||||||||||||||||||||||||||||||||||
| December 31, 2020 | |||||||||||||||||||||||||||||||||||||||||||||||
| Expected Maturity Dates | |||||||||||||||||||||||||||||||||||||||||||||||
| 2021 | 2022 | 2023 | 2024 | 2025 | There- after | Total | Fair Value | ||||||||||||||||||||||||||||||||||||||||
| (Thousands of Dollars, Except Interest Rates) | |||||||||||||||||||||||||||||||||||||||||||||||
| Fixed-rate debt | $ | 300,000 | $ | 250,000 | $ | — | $ | — | $ | 600,000 | $ | 1,972,140 | $ | 3,122,140 | $ | 3,396,542 | |||||||||||||||||||||||||||||||
| Weighted-average rate | 6.8 | % | 4.8 | % | — | — | 5.8 | % | 6.0 | % | 5.9 | % | — | ||||||||||||||||||||||||||||||||||
| Variable-rate debt | $ | — | $ | — | $ | 57,000 | $ | — | $ | — | $ | 402,500 | $ | 459,500 | $ | 402,836 | |||||||||||||||||||||||||||||||
| Weighted-average rate | — | — | 2.3 | % | — | — | 7.0 | % | 6.4 | % | — | ||||||||||||||||||||||||||||||||||||
We utilized forward-starting interest rate swap agreements to lock in the rate on the interest payments related to forecasted debt issuances. Please refer to Notes 2 and 16 of the Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplementary Data” for a more detailed discussion of our interest rate swaps.
Since the operations of our fuels marketing segment expose us to commodity price risk, we also use derivative instruments to attempt to mitigate the effects of commodity price fluctuations. Derivative financial instruments associated with commodity price risk were not material for any periods presented.
51
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
Management’s Report on Internal Control over Financial Reporting
Our management is responsible for establishing and maintaining effective internal control over financial reporting as defined in Rule 13a-15(f) under the Securities Exchange Act of 1934. Our management assessed the effectiveness of NuStar Energy L.P.’s internal control over financial reporting as of December 31, 2021. In its evaluation, management used the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission (COSO) in Internal Control-Integrated Framework (2013). Based on this assessment, management believes that, as of December 31, 2021, our internal control over financial reporting was effective based on those criteria.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Therefore, even those systems determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation.
The effectiveness of internal control over financial reporting as of December 31, 2021 has been audited by KPMG LLP, the independent registered public accounting firm who audited our consolidated financial statements included in this Form 10-K. KPMG LLP’s attestation on the effectiveness of our internal control over financial reporting appears on page 56.
52
Report of Independent Registered Public Accounting Firm
To the Board of Directors of NuStar GP, LLC
and Unitholders of NuStar Energy L.P.:
Opinion on the Consolidated Financial Statements
We have audited the accompanying consolidated balance sheets of NuStar Energy L.P. and subsidiaries (the Partnership) as of December 31, 2021 and 2020, the related consolidated statements of income (loss), comprehensive income (loss), cash flows, and partners’ equity and mezzanine equity for each of the years in the three-year period ended December 31, 2021, and the related notes (collectively, the consolidated financial statements). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Partnership as of December 31, 2021 and 2020, and the results of its operations and its cash flows for each of the years in the three-year period ended December 31, 2021, in conformity with U.S. generally accepted accounting principles.
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the Partnership’s internal control over financial reporting as of December 31, 2021, based on criteria established in Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission, and our report dated February 24, 2022 expressed an unqualified opinion on the effectiveness of the Partnership’s internal control over financial reporting.
Basis for Opinion
These consolidated financial statements are the responsibility of the Partnership’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Partnership in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. We believe that our audits provide a reasonable basis for our opinion.
Critical Audit Matter
The critical audit matter communicated below is a matter arising from the current period audit of the consolidated financial statements that was communicated or required to be communicated to the audit committee and that: (1) relates to accounts or disclosures that are material to the consolidated financial statements and (2) involved our especially challenging, subjective, or complex judgments. The communication of a critical audit matter does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates.
Identification of triggering events related to the recoverability of certain long-lived assets or asset groups
As discussed in Note 2, the Partnership tests long-lived assets, including property, plant, and equipment, for impairment whenever events or changes in circumstances (triggering events) indicate that the carrying amount may not be recoverable. The Partnership evaluates recoverability using undiscounted estimated net cash flows generated by the related asset or asset group considering the intended use of the asset. The balance of property, plant, and equipment, net as of December 31, 2021 was $3,541.6 million, or 68.7% of total assets, of which certain assets or asset groups were not supported by existing revenue generating contacts or have not historically had consistent revenue generating activities.
We identified the assessment of the identification of triggering events related to the recoverability of certain long-lived assets or asset groups as a critical audit matter. Challenging auditor judgment was required to assess the identification of triggering events for certain long-lived assets or asset groups that were not supported by existing revenue generating contracts or have not historically had consistent revenue generating activities. Specifically, this assessment included the evaluation of subjective qualitative considerations, such as alternative customers and alternative uses for the asset or asset group, and the Partnership’s intent for the asset or asset group.
53
The following are the primary procedures we performed to address this critical audit matter. We evaluated the design and tested the operating effectiveness of certain internal controls over the Partnership’s triggering event assessment. This included controls over the identification of long-lived asset groups that would be at greater risk for a triggering event and evaluation of the qualitative considerations in assessing the identification of a triggering event. We examined the Partnership’s analysis of the long-lived assets and asset groups identified to be evaluated for a potential triggering event and assessed the factors considered in determining the identification of a triggering event. Specifically, we evaluated the Partnership’s assessment of the factors considered, including alternative customers, alternative uses for the assets or asset group, and the Partnership’s intent for the assets or asset group by evaluating internal and external documentation. Documentation evaluated included internal presentations, draft customer contracts, publicly available market data, and communications between the Partnership and potential customers.
We have served as the Partnership’s auditor since 2004.
/s/ KPMG LLP
San Antonio, Texas
February 24, 2022
54
Report of Independent Registered Public Accounting Firm
The Board of Directors of NuStar GP, LLC
and Unitholders of NuStar Energy L.P.:
Opinion on Internal Control Over Financial Reporting
We have audited NuStar Energy L.P. and subsidiaries' (the Partnership) internal control over financial reporting as of December 31, 2021, based on criteria established in Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2021, based on criteria established in Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission.
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated balance sheets of the Partnership as of December 31, 2021 and 2020, the related consolidated statements of income (loss), comprehensive income (loss), cash flows, and partners’ equity and mezzanine equity for each of the years in the three-year period ended December 31, 2021, and the related notes (collectively, the consolidated financial statements), and our report dated February 24, 2022 expressed an unqualified opinion on those consolidated financial statements.
Basis for Opinion
The Partnership’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management's Report on Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Partnership’s internal control over financial reporting based on our audit. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Partnership in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audit also included performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.
Definition and Limitations of Internal Control Over Financial Reporting
A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
/s/ KPMG LLP
San Antonio, Texas
February 24, 2022
55
NUSTAR ENERGY L.P. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(Thousands of Dollars, Except Unit Data)
| December 31, | |||||||||||
| 2021 | 2020 | ||||||||||
| Assets | |||||||||||
| Current assets: | |||||||||||
| Cash and cash equivalents | $ | $ | |||||||||
| Accounts receivable | |||||||||||
| Inventories | |||||||||||
| Prepaid and other current assets | |||||||||||
| Total current assets | |||||||||||
| Property, plant and equipment, at cost | |||||||||||
| Accumulated depreciation and amortization | ( | ( | |||||||||
| Property, plant and equipment, net | |||||||||||
| Intangible assets, net | |||||||||||
| Goodwill | |||||||||||
| Other long-term assets, net | |||||||||||
| Total assets | $ | $ | |||||||||
| Liabilities, Mezzanine Equity and Partners’ Equity | |||||||||||
| Current liabilities: | |||||||||||
| Accounts payable | $ | $ | |||||||||
| Current portion of finance lease obligations | |||||||||||
| Accrued interest payable | |||||||||||
| Accrued liabilities | |||||||||||
| Taxes other than income tax | |||||||||||
| Total current liabilities | |||||||||||
| Long-term debt, less current portion | |||||||||||
| Deferred income tax liability | |||||||||||
| Other long-term liabilities | |||||||||||
| Total liabilities | |||||||||||
Commitments and contingencies (Note 14) | |||||||||||
Series D preferred limited partners ( December 31, 2021 and 2020) (Note 17) | |||||||||||
Partners’ equity (Note 18): | |||||||||||
| Preferred limited partners: | |||||||||||
Series A ( | |||||||||||
Series B ( | |||||||||||
Series C ( | |||||||||||
Common limited partners ( as of December 31, 2021 and 2020, respectively) | |||||||||||
| Accumulated other comprehensive loss | ( | ( | |||||||||
| Total partners’ equity | |||||||||||
| Total liabilities, mezzanine equity and partners’ equity | $ | $ | |||||||||
See Notes to Consolidated Financial Statements.
56
NUSTAR ENERGY L.P. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF INCOME (LOSS)
(Thousands of Dollars, Except Unit and Per Unit Data)
| Year Ended December 31, | |||||||||||||||||
| 2021 | 2020 | 2019 | |||||||||||||||
| Revenues: | |||||||||||||||||
| Service revenues | $ | $ | $ | ||||||||||||||
| Product sales | |||||||||||||||||
| Total revenues | |||||||||||||||||
| Costs and expenses: | |||||||||||||||||
| Costs associated with service revenues: | |||||||||||||||||
| Operating expenses (excluding depreciation and amortization expense) | |||||||||||||||||
| Depreciation and amortization expense | |||||||||||||||||
| Total costs associated with service revenues | |||||||||||||||||
| Cost associated with product sales | |||||||||||||||||
| Asset impairment losses | |||||||||||||||||
| Goodwill impairment losses | |||||||||||||||||
| General and administrative expenses (excluding depreciation and amortization expense) | |||||||||||||||||
| Other depreciation and amortization expense | |||||||||||||||||
| Total costs and expenses | |||||||||||||||||
| Operating income | |||||||||||||||||
| Interest expense, net | ( | ( | ( | ||||||||||||||
| Loss on extinguishment of debt | ( | ||||||||||||||||
| Other income (expense), net | ( | ||||||||||||||||
| Income (loss) from continuing operations before income tax expense | ( | ||||||||||||||||
| Income tax expense | |||||||||||||||||
| Income (loss) from continuing operations | ( | ||||||||||||||||
| Loss from discontinued operations, net of tax | ( | ||||||||||||||||
| Net income (loss) | $ | $ | ( | $ | ( | ||||||||||||
Basic and diluted net (loss) income per common unit: | |||||||||||||||||
| Continuing operations | $ | ( | $ | ( | $ | ||||||||||||
| Discontinued operations | ( | ||||||||||||||||
Total (Note 19) | $ | ( | $ | ( | $ | ( | |||||||||||
| Basic weighted-average common units outstanding | |||||||||||||||||
| Diluted weighted-average common units outstanding | |||||||||||||||||
See Notes to Consolidated Financial Statements.
57
NUSTAR ENERGY L.P. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
(Thousands of Dollars)
| Year Ended December 31, | |||||||||||||||||
| 2021 | 2020 | 2019 | |||||||||||||||
| Net income (loss) | $ | $ | ( | $ | ( | ||||||||||||
| Other comprehensive income (loss): | |||||||||||||||||
| Foreign currency translation adjustment | |||||||||||||||||
Net gain (loss) on pension and other postretirement benefit adjustments, net of income tax (expense) benefit of ($ | ( | ( | |||||||||||||||
| Change in unrealized loss on cash flow hedges | ( | ( | |||||||||||||||
| Reclassification of loss on cash flow hedges to interest expense, net | |||||||||||||||||
| Total other comprehensive income (loss) | ( | ( | |||||||||||||||
| Comprehensive income (loss) | $ | $ | ( | $ | ( | ||||||||||||
See Notes to Consolidated Financial Statements.
58
NUSTAR ENERGY L.P. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Thousands of Dollars)
| Year Ended December 31, | |||||||||||||||||
| 2021 | 2020 | 2019 | |||||||||||||||
| Cash Flows from Operating Activities: | |||||||||||||||||
| Net income (loss) | $ | $ | ( | $ | ( | ||||||||||||
Adjustments to reconcile net income (loss) to net cash provided by operating activities: | |||||||||||||||||
| Depreciation and amortization expense | |||||||||||||||||
| Amortization of unit-based compensation | |||||||||||||||||
| Amortization of debt related items | |||||||||||||||||
| (Gain) loss from sale or disposition of assets | ( | ||||||||||||||||
| Gain from insurance recoveries | ( | ||||||||||||||||
| Asset and goodwill impairment losses | |||||||||||||||||
| Loss on extinguishment of debt | |||||||||||||||||
| Deferred income tax (benefit) expense | ( | ( | |||||||||||||||
Changes in current assets and current liabilities (Note 20) | ( | ( | |||||||||||||||
| Decrease (increase) in other long-term assets | ( | ||||||||||||||||
| (Decrease) increase in other long-term liabilities | ( | ( | |||||||||||||||
| Other, net | ( | ||||||||||||||||
| Net cash provided by operating activities | |||||||||||||||||
| Cash Flows from Investing Activities: | |||||||||||||||||
| Capital expenditures | ( | ( | ( | ||||||||||||||
| Change in accounts payable related to capital expenditures | ( | ( | |||||||||||||||
| Proceeds from insurance recoveries | |||||||||||||||||
| Proceeds from sale or disposition of assets | |||||||||||||||||
| Other, net | ( | ||||||||||||||||
| Net cash provided by (used in) investing activities | ( | ( | |||||||||||||||
| Cash Flows from Financing Activities: | |||||||||||||||||
| Proceeds from Term Loan, net of discount and issuance costs | |||||||||||||||||
| Proceeds from note offerings, net of issuance costs | |||||||||||||||||
| Proceeds from other long-term debt borrowings | |||||||||||||||||
| Proceeds from short-term debt borrowings | |||||||||||||||||
| Term Loan repayment, including debt extinguishment costs | ( | ||||||||||||||||
| Other long-term debt repayments | ( | ( | ( | ||||||||||||||
| Short-term debt repayments | ( | ( | |||||||||||||||
| Proceeds from issuance of common units | |||||||||||||||||
| Distributions to preferred unitholders | ( | ( | ( | ||||||||||||||
| Distributions to common unitholders | ( | ( | ( | ||||||||||||||
| Payments for termination of interest rate swaps | ( | ||||||||||||||||
| Payment of tax withholding for unit-based compensation | ( | ( | ( | ||||||||||||||
| Decrease in cash book overdrafts | ( | ( | ( | ||||||||||||||
| Other, net | ( | ( | ( | ||||||||||||||
| Net cash used in financing activities | ( | ( | ( | ||||||||||||||
| Effect of foreign exchange rate changes on cash | ( | ||||||||||||||||
| Net (decrease) increase in cash, cash equivalents and restricted cash | ( | ||||||||||||||||
| Cash, cash equivalents and restricted cash as of the beginning of the period | |||||||||||||||||
| Cash, cash equivalents and restricted cash as of the end of the period | $ | $ | $ | ||||||||||||||
See Notes to Consolidated Financial Statements.
59
NUSTAR ENERGY L.P. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF PARTNERS’ EQUITY AND MEZZANINE EQUITY
(Thousands of Dollars, Except Per Unit Data)
| Limited Partners | Mezzanine Equity | ||||||||||||||||||||||||||||||||||
| Preferred | Common | Accumulated Other Comprehensive Loss | Total Partners’ Equity (Note 18) | Series D Preferred Limited Partners (Note 17) | Total | ||||||||||||||||||||||||||||||
| Balance as of January 1, 2019 | $ | $ | $ | ( | $ | $ | $ | ||||||||||||||||||||||||||||
| Net income (loss) | ( | ( | ( | ||||||||||||||||||||||||||||||||
| Other comprehensive loss | ( | ( | — | ( | |||||||||||||||||||||||||||||||
| Distributions to partners: | |||||||||||||||||||||||||||||||||||
| Series A, B and C preferred | ( | — | — | ( | — | ( | |||||||||||||||||||||||||||||
Common ($ | — | ( | — | ( | — | ( | |||||||||||||||||||||||||||||
| Series D preferred | — | — | — | — | ( | ( | |||||||||||||||||||||||||||||
| Issuance of common units | — | — | |||||||||||||||||||||||||||||||||
| Unit-based compensation | — | ||||||||||||||||||||||||||||||||||
| Series D Preferred Unit accretion | — | ( | — | ( | |||||||||||||||||||||||||||||||
| Other | ( | ( | ( | ( | |||||||||||||||||||||||||||||||
| Balance as of December 31, 2019 | ( | ||||||||||||||||||||||||||||||||||
| Net income (loss) | ( | ( | ( | ||||||||||||||||||||||||||||||||
| Other comprehensive loss | ( | ( | — | ( | |||||||||||||||||||||||||||||||
| Distributions to partners: | |||||||||||||||||||||||||||||||||||
| Series A, B and C preferred | ( | — | — | ( | — | ( | |||||||||||||||||||||||||||||
Common ($ | — | ( | — | ( | — | ( | |||||||||||||||||||||||||||||
| Series D preferred | — | — | — | — | ( | ( | |||||||||||||||||||||||||||||
| Unit-based compensation | — | ||||||||||||||||||||||||||||||||||
| Series D Preferred Unit accretion | — | ( | — | ( | |||||||||||||||||||||||||||||||
| Other | ( | ( | ( | ( | |||||||||||||||||||||||||||||||
| Balance as of December 31, 2020 | ( | ||||||||||||||||||||||||||||||||||
| Net income (loss) | ( | ( | |||||||||||||||||||||||||||||||||
| Other comprehensive income | — | ||||||||||||||||||||||||||||||||||
| Distributions to partners: | |||||||||||||||||||||||||||||||||||
| Series A, B and C preferred | ( | — | — | ( | — | ( | |||||||||||||||||||||||||||||
Common ($ | — | ( | — | ( | — | ( | |||||||||||||||||||||||||||||
| Series D preferred | — | — | — | — | ( | ( | |||||||||||||||||||||||||||||
| Unit-based compensation | — | ||||||||||||||||||||||||||||||||||
| Series D Preferred Unit accretion | — | ( | — | ( | |||||||||||||||||||||||||||||||
| Other | ( | ( | |||||||||||||||||||||||||||||||||
| Balance as of December 31, 2021 | $ | $ | $ | ( | $ | $ | $ | ||||||||||||||||||||||||||||
See Notes to Consolidated Financial Statements.
60
NUSTAR ENERGY L.P. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Years Ended December 31, 2021, 2020 and 2019
1. ORGANIZATION AND OPERATIONS
Organization
NuStar Energy L.P. (NYSE: NS) is a Delaware limited partnership primarily engaged in the transportation, terminalling and storage of petroleum products and renewable fuels and the transportation of anhydrous ammonia. Unless otherwise indicated, the terms “NuStar Energy,” “NS,” “the Partnership,” “we,” “our” and “us” are used in this report to refer to NuStar Energy L.P., to one or more of our consolidated subsidiaries or to all of them taken as a whole. Our business is managed under the direction of the board of directors of NuStar GP, LLC, the general partner of our general partner, Riverwalk Logistics, L.P., both of which are indirectly wholly owned subsidiaries of ours.
Operations
We conduct our operations through our subsidiaries, primarily NuStar Logistics, L.P. (NuStar Logistics) and NuStar Pipeline Operating Partnership L.P. (NuPOP). We have three business segments: pipeline, storage and fuels marketing.
Pipeline. We own 3,205 miles of refined product pipelines and 2,230 miles of crude oil pipelines, as well as 5.6 million barrels of crude oil storage capacity, which comprise our Central West System. In addition, we own 2,500 miles of refined product pipelines, consisting of the East and North Pipelines, and a 2,000 -mile ammonia pipeline, which comprise our Central East System. The East and North Pipelines have storage capacity of 7.4 million barrels. We charge tariffs on a per barrel basis for transporting refined products, crude oil and other feedstocks in our refined product and crude oil pipelines and on a per ton basis for transporting anhydrous ammonia in the Ammonia Pipeline.
Storage. We own terminal and storage facilities in the United States, Canada and Mexico, with 44.2 million barrels of storage capacity. Our terminal and storage facilities provide storage, handling and other services on a fee basis for refined products, crude oil, specialty chemicals, renewable fuels and other liquids.
Fuels Marketing. The fuels marketing segment includes our bunkering operations in the Gulf Coast, as well as certain of our blending operations associated with our Central East System.
Recent Developments
Point Tupper Terminal Sale Agreement. On February 11, 2022, we entered into an agreement to sell the equity interests in our wholly owned subsidiaries that own our Point Tupper terminal facility to EverWind Fuels for $60.0 million. The terminal facility has a storage capacity of 7.8 million barrels and is included in the storage segment. We expect to complete the sale in the first half of 2022 and will utilize the sales proceeds to improve our debt metrics. Please refer to Note 25 for more information.
Debt Amendments. On January 28, 2022, we amended and restated our $1.0 billion unsecured revolving credit agreement to extend the maturity to April 27, 2025, replace the LIBOR-based interest rate and modify other terms. Also on January 28, 2022, we amended our $100.0 million receivables financing agreement to extend the scheduled termination date to January 31, 2025, replace the LIBOR-based interest rate and modify other terms. Please refer to Note 12 for more information.
Eastern U.S. Terminals Disposition. On October 8, 2021, we completed the sale of nine U.S. terminal and storage facilities, including all our North East Terminals and one terminal in Florida (the Eastern U.S. Terminal Operations) to Sunoco LP for $250.0 million in cash (the Eastern U.S. Terminals Disposition). We recorded asset and goodwill impairment losses of $95.7 million and $34.1 million, respectively, in the third quarter of 2021. Please see Note 4 for further discussion.
Houston Pipeline Impairment. In the third quarter of 2021, we recorded a long-lived asset impairment charge of $59.2 million related to the southern section of our Houston refined product pipeline. Please see Note 4 for further discussion.
Senior Notes. On November 1, 2021, we repaid our $250.0 million of 4.75 % senior notes due February 1, 2022 with proceeds from the Eastern U.S. Terminals Disposition. On February 1, 2021 we repaid our $300.0 million of 6.75 % senior notes at maturity with borrowings under our Revolving Credit Agreement.
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Other Events
Selby Terminal Fire. On October 15, 2019, our terminal facility in Selby, California experienced a fire that destroyed two storage tanks and temporarily shut down the terminal . The property damage was isolated, and in the fourth quarter of 2019, we incurred losses of $5.4 million, which represent the aggregate amount of our deductibles under various insurance policies. We received insurance proceeds of $28.5 million and $35.0 million, for the years ended December 31, 2021 and 2020, respectively. Gains from business interruption insurance of $4.0 million, $6.7 million and $1.3 million for the years ended December 31, 2021, 2020 and 2019, respectively, are included in “Operating expenses” in the consolidated statements of income (loss). For the year ended December 31, 2021, we recorded a gain of $14.9 million for the amount by which the insurance recoveries exceeded our expenses incurred to date, which is included in “Other income (expense), net” in the consolidated statements of income (loss). Insurance proceeds related to cleanup costs and business interruption are included in “Cash flows from operating activities” in the consolidated statements of cash flows. In addition, we received $5.8 million of insurance proceeds in January 2022. We believe we have adequate insurance to offset additional costs.
Sale of Texas City Terminals. On December 7, 2020, we sold the equity interests in our wholly owned subsidiaries that owned two terminals in Texas City, Texas for $106.0 million. We recorded a non-cash loss of $34.7 million and utilized the sales proceeds to improve our debt metrics. Please refer to Note 4 for further discussion.
Senior Notes. On September 14, 2020, NuStar Logistics issued $600.0 million of 5.75 % senior notes due October 1, 2025 and $600.0 million of 6.375 % senior notes due October 1, 2030. We received proceeds of $1,182.0 million, net of issuance costs of $18.0 million, which we used to repay outstanding borrowings under the Term Loan, as defined below, as well as outstanding borrowings under our revolving credit agreement. On September 1, 2020, we repaid our $450.0 million of 4.80 % senior notes at maturity with borrowings under our revolving credit agreement. Please refer to Note 12 for further discussion.
Term Loan Credit Agreement. On April 19, 2020, NuStar Energy and NuStar Logistics entered into an unsecured term loan credit agreement with certain lenders and Oaktree Fund Administration, LLC, as administrative agent for the lenders (the Term Loan). The Term Loan provided for an aggregate commitment of up to $750.0 million pursuant to a three-year unsecured term loan credit facility. On April 21, 2020 we drew $500.0 million, which we repaid on September 16, 2020. The repayment required certain contractual premiums, and we recognized a loss of $137.9 million in the third quarter of 2020. On February 16, 2021, we terminated the Term Loan. Please refer to Note 12 for further discussion about the Term Loan.
Sale of St. Eustatius Operations. On July 29, 2019, we sold our St. Eustatius terminal and bunkering operations (the St. Eustatius Operations) for net proceeds of approximately $230.0 million (the St. Eustatius Disposition). In 2019, we recorded long-lived asset and goodwill impairment charges totaling $336.8 million related to the St. Eustatius Operations in “Loss from discontinued operations, net of tax” on our consolidated statement of loss. In the second quarter of 2019, we determined the St. Eustatius Operations and the European operations, which we sold in 2018, met the requirements to be reported as discontinued operations, and as a result, we reclassified certain balances to assets held for sale and liabilities held for sale and certain revenues and expenses to discontinued operations for all applicable periods presented.
2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Consolidation
The accompanying consolidated financial statements represent the consolidated operations of the Partnership and our subsidiaries. Inter-partnership balances and transactions have been eliminated in consolidation. The operations of certain pipelines and terminals in which we own an undivided interest are proportionately consolidated in the accompanying consolidated financial statements.
Use of Estimates
The preparation of consolidated financial statements in conformity with U.S. generally accepted accounting principles (GAAP) requires management to make estimates and assumptions that affect the amounts reported in the consolidated financial statements and accompanying notes. Actual results could differ from those estimates. On an ongoing basis, management reviews its estimates based on currently available information. Management may revise estimates due to changes in facts and circumstances.
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Accounts Receivable
Trade receivables are carried at amortized cost, net of a valuation allowance for current expected credit losses. We extend credit to certain customers after review of various credit indicators, including the customer’s credit rating, and obtain letters of credit, guarantees or collateral as deemed necessary. We monitor our ongoing credit exposure through active review of customer balances against contract terms and due dates and pool customer receivables based upon days outstanding, which is our primary credit risk indicator. Our review activities include timely account reconciliations, dispute resolution and payment confirmations.
Inventories
Inventories consist of petroleum products, materials and supplies. Inventories are valued at the lower of cost or net realizable value. Cost is determined using the weighted-average cost method. Our inventory, other than materials and supplies, consists of one end-product category, petroleum products, which we include in the fuels marketing segment. Accordingly, we determine lower of cost or net realizable value adjustments on an aggregate basis. Materials and supplies are valued at the lower of average cost or net realizable value.
Restricted Cash
As of December 31, 2021 and 2020, we have restricted cash representing legally restricted funds that are unavailable for general use totaling $8.8
Property, Plant and Equipment
We record additions to property, plant and equipment, including reliability and strategic capital expenditures, at cost. Repair and maintenance costs associated with existing assets that are minor in nature and do not extend the useful life of existing assets are charged to operating expenses as incurred. Depreciation of property, plant and equipment is recorded on a straight-line basis over the estimated useful lives of the related assets. When property or equipment is retired, sold or otherwise disposed of, the difference between the carrying value and the net proceeds is recognized in “Other income (expense), net” or “Loss from discontinued operations, net of tax” in the consolidated statements of income (loss) in the year of disposition. We capitalize overhead costs and interest costs incurred on funds used to construct property, plant and equipment while the asset is under construction. The overhead costs and capitalized interest are recorded as part of the asset to which they relate and are amortized over the asset’s estimated useful life as a component of depreciation expense.
Leases - Lessee
We lease assets used in our operations, including land, docks, and marine vessels. We record all leases on our consolidated balance sheet except for those leases with an initial term of 12 months or less, which are expensed on a straight-line basis over the lease term. We use judgment in determining the reasonably certain lease term and consider factors such as the nature and utility of the leased asset, as well as the importance of the leased asset to our operations. We calculate the present value of our lease liabilities based upon our incremental borrowing rate unless the rate implicit in the lease is readily determinable. For all of our asset classes except the other pipeline and terminal equipment asset class, we combine lease and non-lease components and account for them as a single lease component.
Certain of our leases are subject to variable payment arrangements, the most notable of which include:
•dockage and wharfage charges, which are based on volumes moved over leased docks and are included in our calculation of our lease payments based on minimum throughput volume requirements. We recognize charges on excess throughput volumes in profit or loss in the period in which the obligation for those payments is incurred; and
•consumer price index adjustments, which are measured and included in the calculation of our lease payments based on the consumer price index at the commencement date. We recognize changes in lease payments as a result of changes in the consumer price index in profit or loss in the period in which those payments are made.
Goodwill
We assess goodwill for impairment annually on October 1, or more frequently if events or changes in circumstances indicate it might be impaired. We have the option to first assess qualitative factors to determine whether it is necessary to perform a quantitative goodwill impairment test. We elected to bypass the qualitative assessment for all reporting units as of October 1, 2021 and October 1, 2020 and performed quantitative assessments, resulting in the determination that goodwill was not
We measure goodwill impairment as the excess of each reporting unit’s carrying value over its fair value, not to exceed the carrying amount of goodwill for that reporting unit. The carrying value of each reporting unit equals the total identified assets
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(including goodwill) less the sum of each reporting unit’s identified liabilities. We used reasonable and supportable methods to assign the assets and liabilities to the appropriate reporting units in a consistent manner.
As of December 31, 2021 and 2020, our reporting units to which goodwill has been allocated consisted of the following:
•crude oil pipelines;
•refined product pipelines; and
•terminals, excluding our Point Tupper facility and our refinery crude storage tanks.
Please see Notes 4 and 10 for a discussion of the balances of and changes in the carrying amount of goodwill.
We recognize an impairment of goodwill if the carrying value of a reporting unit that contains goodwill exceeds its estimated fair value. In order to estimate the fair value of the reporting unit, including goodwill, management must make certain estimates and assumptions that affect the total fair value of the reporting unit including, among other things, an assessment of market conditions, projected cash flows, discount rates and growth rates. Management’s estimates of projected cash flows related to the reporting unit include, but are not limited to, future earnings of the reporting unit, assumptions about the use or disposition of the asset, estimated remaining life of the asset, and future expenditures necessary to maintain the asset’s existing service potential. We calculate the estimated fair value of each of our reporting units using a weighted-average of values calculated using an income approach and a market approach. The income approach involves estimating the fair value of each reporting unit by discounting its estimated future cash flows using a discount rate that would be consistent with a market participant’s assumption. The market approach bases the fair value measurement on information obtained from observed stock prices of public companies and recent merger and acquisition transaction data of comparable entities.
Impairment of Long-Lived Assets
We review long-lived assets, including property, plant and equipment, for impairment whenever events or changes in circumstances indicate that the carrying amount may not be recoverable. We evaluate recoverability using undiscounted estimated net cash flows generated by the related asset or asset group. If the results of that evaluation indicate that the undiscounted cash flows are less than the carrying amount of the asset (i.e., the asset is not recoverable) we perform an impairment analysis. If our intent is to hold the asset for continued use, we determine the amount of impairment as the amount by which the net carrying value exceeds its fair value. If our intent is to sell the asset, and the criteria required to classify an asset as held for sale are met, we determine the amount of impairment as the amount by which the net carrying amount exceeds its fair value less costs to sell. See Note 4 for a discussion of our long-lived asset impairment charges. We believe that the carrying amounts of our long-lived assets as of December 31, 2021 are recoverable.
Income Taxes
We are a limited partnership and generally are not subject to federal or state income taxes. Accordingly, our taxable income or loss, which may vary substantially from income or loss reported for financial reporting purposes, is generally included in the federal and state income tax returns of our partners. For transfers of publicly held common units subsequent to our initial public offering, we have made an election permitted by Section 754 of the Internal Revenue Code (the Code) to adjust the common unit purchaser’s tax basis in our underlying assets to reflect the purchase price of the units. This results in an allocation of taxable income and expenses to the purchaser of the common units, including depreciation deductions and gains and losses on sales of assets, based upon the new unitholder’s purchase price for the common units.
We conduct certain of our operations through taxable wholly owned corporate subsidiaries. We account for income taxes related to our taxable subsidiaries using the asset and liability method. Under this method, we recognize deferred tax assets and liabilities for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. We measure deferred taxes using enacted tax rates expected to apply to taxable income in the year those temporary differences are expected to be recovered or settled.
We recognize a tax position if it is more likely than not that the tax position will be sustained, based on the technical merits of the position, upon examination. We record uncertain tax positions in the financial statements at the largest amount of benefit that is more likely than not to be realized. We had no
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Asset Retirement Obligations
We record a liability for asset retirement obligations at the fair value of the estimated costs to retire a tangible long-lived asset at the time we incur that liability, which is generally when the asset is purchased, constructed or leased, when we have a legal obligation to incur costs to retire the asset and when a reasonable estimate of the fair value of the obligation can be made. If a reasonable estimate cannot be made at the time the liability is incurred, we record the liability when sufficient information is available to estimate the fair value.
We have asset retirement obligations with respect to certain of our assets due to various legal obligations to clean and/or dispose of those assets at the time they are retired. However, these assets can be used for an extended and indeterminate period of time as long as they are properly maintained and/or upgraded. It is our practice and current intent to maintain our assets and continue making improvements to those assets based on technological advances. As a result, we believe that our assets have indeterminate lives for purposes of estimating asset retirement obligations because dates or ranges of dates upon which we would retire these assets cannot reasonably be estimated at this time. When a date or range of dates can reasonably be estimated for the retirement of any asset, we estimate the costs of performing the retirement activities and record a liability for the fair value of these costs.
We also have legal obligations in the form of leases and right-of-way agreements, which require us to remove certain of our assets upon termination of the agreement. However, these lease or right-of-way agreements generally contain automatic renewal provisions that extend our rights indefinitely or we have other legal means available to extend our rights. Liabilities for conditional asset retirement obligations related to the retirement of terminal assets with lease and right-of-way agreements were not material as of December 31, 2021 and 2020.
Environmental Remediation Costs
Environmental remediation costs are expensed and an associated accrual established when site restoration and environmental remediation and cleanup obligations are either known or considered probable and can be reasonably estimated. These environmental obligations are based on estimates of probable undiscounted future costs using currently available technology and applying current regulations, as well as our own internal environmental policies. The environmental liabilities have not been reduced by possible recoveries from third parties. Environmental costs include initial site surveys, costs for remediation and restoration and ongoing monitoring costs, as well as fines, damages and other costs, when applicable and estimable. Adjustments to initial estimates are recorded, from time to time, to reflect changing circumstances and estimates based upon additional information developed in subsequent periods.
Revenue Recognition
Revenue-Generating Activities. Revenues for the pipeline segment are derived from interstate and intrastate pipeline transportation of refined products, crude oil and anhydrous ammonia and the applicable pipeline tariff on a per barrel basis for crude oil or refined products and on a per ton basis for ammonia. Revenues generated from product sales in the pipeline segment relate to surplus pipeline loss allowance volumes.
Revenues for the storage segment include fees for tank storage agreements, under which a customer agrees to pay for a certain amount of storage in a tank over a period of time (storage terminal revenues), and throughput agreements, under which a customer pays a fee per barrel for volumes moving through our terminals (throughput terminal revenues). Our terminals also provide blending, additive injections, handling and filtering services for which we charge additional fees. Certain of our facilities charge fees to provide marine services such as pilotage, tug assistance, line handling, launch service, emergency response services and other ship services (all of which are considered optional services). We are considered to be the lessor in certain revenue contracts. To the extent that a contract contains both lease and non-lease components, such as when we provide both storage capacity and optional services to a customers, we combine the lease and non-lease components and account for the transaction based on the predominant component.
Revenues for the fuels marketing segment are derived from the sale of petroleum products.
Within our pipeline and storage segments, we provide services on uninterruptible and interruptible bases. Uninterruptible services within our pipeline segment typically result from contracts that contain take-or-pay minimum volume commitments (MVCs) from the customer. Contracts with MVCs obligate the customer to pay for that minimum amount. If a customer fails to meet its MVC for the applicable service period, the customer is obligated to pay a deficiency fee based upon the shortfall
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between the actual volumes transported or stored and the MVC for that service period (deficiency payments). In exchange, those contracts with MVCs obligate us to stand ready to transport volumes up to the customer’s MVC.
Within our storage segment, uninterruptible services arise from contracts containing a fixed monthly fee for the portion of storage capacity reserved by the customer. These contracts require that the customer pay the fixed monthly fee, regardless of whether or not it uses our storage facility (i.e., take-or-pay obligation), and that we stand ready to store that volume. Interruptible services within our pipeline and storage segments are generally provided when and to the extent we determine the requested capacity is available. The customer typically pays a per-unit rate for the actual quantities of services it receives.
For the majority of our contracts, we recognize revenue in the amount to which we have a right to invoice. Generally, payment terms do not exceed 30 days.
Performance Obligations. The majority of our contracts contain a single performance obligation. For our pipeline segment, the single performance obligation encompasses multiple activities necessary to deliver our customers’ products to their destinations. Typically, we satisfy this performance obligation over time as the product volume is delivered in or out of the pipelines. Certain of our pipeline segment customer contracts include an incentive pricing structure, which provides a discounted rate for the remainder of the contract once the customer exceeds a cumulative volume. The ability to receive discounted future services represents a material right to the customer, which results in a second performance obligation in those contracts.
The performance obligation for our storage segment consists of multiple activities necessary to receive, store and deliver our customers’ products. We typically satisfy this performance obligation over time as the product volume is delivered in or out of the tanks (for throughput terminal revenues) or with the passage of time (for storage terminal revenues).
Product sales contracts generally include a single performance obligation to deliver specified volumes of a commodity, which we satisfy at a point in time, when the product is delivered and the customer obtains control of the commodity.
Optional services described in our contracts do not provide a material right to the customer, and are not considered a separate performance obligation in the contract. If and when a customer elects an optional service, and the terms of the contract are otherwise met, those services become part of the existing performance obligation.
Transaction Price. For uninterruptible services, we determine the transaction price at contract inception based on the guaranteed minimum amount of revenue over the term of the contract. For interruptible services and optional services, we determine the transaction price based on our right to invoice the customer for the value of services provided to the customer for the applicable period.
In certain instances, our customers reimburse us for capital projects, in arrangements referred to as contributions in aid of construction, or CIAC. Typically, in these instances, we receive upfront payments for future services, which are included in the transaction price of the underlying service contract.
We collect taxes on certain revenue transactions to be remitted to governmental authorities, which may include sales, use, value-added and some excise taxes. These taxes are not included in the transaction price and are, therefore, excluded from revenues.
Allocation of Transaction Price. We allocate the transaction price to the single performance obligation that exists in the vast majority of our contracts with customers. For the few contracts that have a second performance obligation, such as those that include an incentive pricing structure, we calculate an average rate based on the estimated total volumes to be delivered over the term of the contract and the resulting estimated total revenue to be billed using the applicable rates in the contract. We allocate the transaction price to the two performance obligations by applying the average rate to product volumes as they are delivered to the customer over the term of the contract. Determining the timing and amount of volumes subject to these incentive pricing contracts requires judgment that can impact the amount of revenue allocated to the two separate performance obligations. We base our estimates on our analysis of expected future production information available from our customers or other sources, which we update at least quarterly.
Some of our MVC contracts include provisions that allow the customer to apply deficiency payments to future service periods (the carryforward period). In those instances, we have not satisfied our performance obligation as we still have the obligation to perform those services, subject to contractual and/or capacity constraints, at the customer’s request. At least quarterly, we assess the customer’s ability to utilize any deficiency payments during the carryforward period. If we receive a deficiency payment
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Income Allocation
Our partnership agreement contains provisions for the allocation of net income to the unitholders. Our net income for each quarterly reporting period is first allocated to the preferred limited partner unitholders in an amount equal to the earned distributions for the respective reporting period. We allocate the remaining net income or loss among the common unitholders.
Basic and Diluted Net Income (Loss) Per Common Unit
Basic and diluted net income (loss) per common unit is determined pursuant to the two-class method. Under this method, all earnings are allocated to our limited partners and participating securities based on their respective rights to receive distributions earned during the period. Participating securities include restricted units awarded under our long-term incentive plans.
We compute basic net income (loss) per common unit by dividing net income (loss) attributable to our common limited partners by the weighted-average number of common units outstanding during the period. We compute diluted net income (loss) per common unit by dividing net income (loss) attributable to our common limited partners by the sum of (i) the weighted-average number of common units outstanding during the period and (ii) the effect of dilutive potential common units outstanding during the period. Dilutive potential common units include contingently issuable performance units awarded and the Series D Preferred Units. See Note 22 for additional information on our performance units, Note 17 for additional information on our Series D Preferred Units and Note 19 for the calculation of basic and diluted net income (loss) per common unit.
Derivative Financial Instruments
When we apply hedge accounting, we formally document all relationships between hedging instruments and hedged items. This process includes identification of the hedging instrument and the hedged transaction, the nature of the risk being hedged and how the hedging instrument’s effectiveness will be assessed. To qualify for hedge accounting, at inception of the hedge we assess whether the derivative instruments that are used in our hedging transactions are expected to be highly effective in offsetting changes in cash flows. Throughout the designated hedge period and at least quarterly, we assess whether the derivative instruments are highly effective and continue to qualify for hedge accounting.
We enter into the forward-starting swaps in order to hedge the risk of changes in the interest payments attributable to changes in the benchmark interest rate during the period from the effective date of the swap to the issuance of the forecasted debt. For forward-starting interest rate swaps designated and qualifying as cash flow hedges, we recognize the fair value of each interest rate swap in the consolidated balance sheets. We record changes in the fair value of the hedge as a component of accumulated other comprehensive income (loss) (AOCI), to the extent those cash flow hedges remain highly effective. If at any point a cash flow hedge ceases to qualify for hedge accounting, changes in the fair value of the hedge are recognized in “Interest expense, net” from that date forward. The amount accumulated in AOCI is amortized into “Interest expense, net” as the forecasted interest payments occur or if the interest payments are probable not to occur.
We classify cash flows associated with our derivative instruments as operating cash flows in the consolidated statements of cash flows, except for receipts or payments associated with terminated forward-starting interest rate swap agreements, which are included in cash flows from financing activities. See Note 16 for additional information regarding our derivative financial instruments.
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Foreign Currency Translation
The functional currencies of our foreign subsidiaries are the local currencies of the countries in which the subsidiaries are located. The assets and liabilities of our foreign subsidiaries with local functional currencies are translated to U.S. dollars at period-end exchange rates, and income and expense items are translated to U.S. dollars at weighted-average exchange rates in effect during the period. These translation adjustments are included in “Accumulated other comprehensive loss” in the equity section of the consolidated balance sheets. Gains and losses on foreign currency transactions are included in “Other income (expense), net” in the consolidated statements of income (loss).
Reclassifications
We have reclassified certain previously reported amounts in the consolidated financial statements and notes to conform to current-period presentation.
3. NEW ACCOUNTING PRONOUNCEMENTS
Accounting for Convertible Instruments and Contracts in an Entity’s Own Equity
In August 2020, the Financial Accounting Standards Board (FASB) issued guidance intended to simplify the accounting for convertible instruments by eliminating certain accounting models for convertible debt instruments and convertible preferred stock, requiring the calculation of diluted earnings-per-unit to include the effect of potential unit settlement for any convertible instruments that may be settled in either cash or units, and amending the disclosure requirements for convertible instruments. The guidance is effective for annual periods beginning after December 15, 2021, and early adoption was permitted for annual periods beginning after December 15, 2020. Amendments may be applied using either a modified retrospective approach or a fully retrospective approach. We adopted the amended guidance on January 1, 2022 using the modified retrospective approach. While the amended guidance did not have a material impact on our financial position, results of operations, or disclosures at adoption, changes to the earnings-per-unit guidance could result in changes to our diluted net income (loss) per common unit.
Reference Rate Reform
In March 2020, the FASB issued guidance intended to provide relief to companies impacted by reference rate reform. The amended guidance provides optional expedients and exceptions for applying GAAP to contracts, hedging relationships and other transactions affected by reference rate reform if certain criteria are met. The publication of U.S. dollar LIBOR rates for the most common tenors is expected to cease after publication on June 30, 2023. As of December 31, 2021, approximately $0.6 billion of our variable-rate debt uses LIBOR as a benchmark for establishing the interest rate. In addition, the distribution rates on our Series A, B and C preferred units convert from fixed rates to floating rates based on LIBOR, beginning in December 2021, June 2022 and December 2022, respectively. The FASB’s guidance is effective as of March 12, 2020 through December 31, 2022. We adopted the guidance on the effective date on a prospective basis. The guidance did not have an impact on our financial position, results of operations or disclosures at transition, but we will continue to evaluate its impact on contracts modified on or before December 31, 2022.
4. DISPOSITIONS, DISCONTINUED OPERATIONS AND IMPAIRMENTS
Eastern U.S. Terminals Disposition
On August 1, 2021, we entered into an agreement (the Purchase Agreement) to sell the Eastern U.S. Terminal Operations to Sunoco LP for $250.0 million in cash. The Eastern U.S. Terminal Operations include terminals in the following locations; Jacksonville, Florida; Andrews Air Force Base, Maryland; Baltimore, Maryland; Piney Point, Maryland; Virginia Beach, Virginia; Paulsboro, New Jersey; and Blue Island, Illinois, as well as both Linden, New Jersey terminals. The Eastern U.S. Terminal Operations had an aggregate storage capacity of 14.8 million barrels and were included in the storage segment. We determined these assets were no longer synergistic with our core assets. The Eastern U.S. Terminal Operations did not qualify for reporting as discontinued operations, as the sale did not represent a strategic shift that would have a major effect on our operations or financial results. We closed the sale on October 8, 2021 and used the proceeds from the sale to reduce debt and thereby improve our debt metrics.
The Eastern U.S. Terminal Operations met the criteria to be classified as held for sale upon our entrance into the Purchase Agreement during the third quarter of 2021. At that time, we allocated goodwill of $34.1 million to the Eastern U.S. Terminal Operations based on its fair value relative to the terminals reporting unit, with which it had been fully integrated. We tested the allocated goodwill for impairment by comparing the fair value of the Eastern U.S. Terminal Operations to its carrying value. The results of our goodwill impairment test indicated that the carrying value of the Eastern U.S. Terminal Operations exceeded its fair value, and we recognized a related goodwill impairment charge of $34.1 million in the third quarter of 2021 to reduce the allocated goodwill to $0 . The goodwill impairment loss is reported in “Goodwill impairment losses” on the consolidated statement of income for the year ended December 31, 2021. We believe that the sales price of $250.0 million provided a
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reasonable indication of the fair value of the Eastern U.S. Terminal Operations as it represents an exit price in an orderly transaction between market participants. The sales price is a quoted price for identical assets and liabilities in a market that is not active and, thus, our fair value estimate falls within Level 2 of the fair value hierarchy.
We compared the remaining carrying value of the Eastern U.S. Terminal Operations, after its goodwill impairment, to its fair value less costs to sell. We recognized an asset impairment loss of $95.7 million in the third quarter of 2021, which is reported in “Asset impairment losses” on the consolidated statement of income for the year ended December 31, 2021. The asset impairment loss included $23.9 million related to intangible assets representing customer contracts and relationships.
Houston Pipeline Impairment
In the third quarter of 2021, we recorded a long-lived asset impairment charge of $59.2 million within our pipeline segment related to our refined product pipeline extending from Mt. Belvieu, Texas to Corpus Christi, Texas (the Houston Pipeline). During the third quarter of 2021, we identified an indication of impairment related to the southern section of the Houston Pipeline, specifically that its physical condition would require significant investment in order to pursue commercial opportunities. Consequently, we separated the pipeline into two distinct assets: the northern and southern sections. Our estimate of the undiscounted cash flows associated with the southern section indicated it was not recoverable. Due to the factors described above, we determined the carrying value of the southern section exceeded its fair value, and reduced its carrying value to $0 . We recorded the asset impairment charge in “Asset impairment losses” on the consolidated statement of income for the year ended December 31, 2021. We determined that the northern portion of the pipeline was not impaired.
Sale of Texas City Terminals
On December 7, 2020, we sold the equity interests in our wholly owned subsidiaries that owned two terminals in Texas City, Texas for $106.0 million (the Texas City Sale). The two terminals had an aggregate storage capacity of 3.0 million barrels and were previously included in our storage segment. We recorded a non-cash loss of $34.7 million in “Other income (expense), net” on our consolidated statement of loss for the year ended December 31, 2020 and utilized the sales proceeds to reduce debt and thereby improve our debt metrics.
Sale of St. Eustatius Operations
On July 29, 2019, we sold the St. Eustatius Operations for net proceeds of approximately $230.0 million. The St. Eustatius Disposition included a 14.3 million barrel storage and terminalling facility and related assets on the island of St. Eustatius in the Caribbean Netherlands. We previously reported the terminal operations in our storage segment and the bunkering operations in our fuels marketing segment. We recognized a non-cash loss on the sale of $3.9 million in “Loss from discontinued operations, net of tax” on the consolidated statement of loss for the year ended December 31, 2019.
Impairments. On January 28, 2019, the U.S. Department of the Treasury’s Office of Foreign Assets Control added Petroleos de Venezuela, S.A. (PDVSA), at the time a customer at the St. Eustatius facility, to its List of Specially Designated Nationals and Blocked Persons (the SDN List). The inclusion of PDVSA on the SDN List required us to wind down our contracts with PDVSA. Prior to winding down such contracts, PDVSA was the St. Eustatius terminal’s largest customer. The effect of the sanctions issued against PDVSA, combined with the progression in the sale negotiations that occurred during March 2019, resulted in triggering events that caused us to evaluate the long-lived assets and goodwill associated with the St. Eustatius terminal and bunkering operations for potential impairment.
With respect to the terminal operations long-lived assets, our estimates of future expected cash flows included the possibility of a near-term sale, as well as continuing to operate the terminal. The carrying value of the terminal’s long-lived assets exceeded our estimate of the total expected cash flows, indicating the long-lived assets were potentially impaired. To determine an impairment amount, we estimated the fair value of the long-lived assets for comparison to the carrying amount of those assets. Our estimate of the fair value considered the expected sales price as well as estimates generated from income and market approaches using a market participant’s assumptions. The estimated fair values resulting from the market and income approaches were consistent with the expected sales price. Therefore, we concluded that the estimated sales price, which was less than the carrying amount of the long-lived assets, represented the best estimate of fair value at March 31, 2019, and we recorded a long-lived asset impairment charge of $297.3 million in the first quarter of 2019 to reduce the carrying value of the assets to their estimated fair value. We recorded an additional impairment charge of $8.4 million in the second quarter of 2019, mainly due to additional capital expenditures incurred in that quarter.
With respect to the goodwill in the Statia Bunkering reporting unit, which consisted of our bunkering operations at the St. Eustatius terminal facility, we estimated the fair value based on the expected sales price discussed above, which is inclusive of the bunkering operations. As a result, we concluded the goodwill was impaired. We measured the goodwill impairment as the
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
difference between the reporting unit’s carrying value and its fair value. Therefore, we recognized a goodwill impairment charge of $31.1 million in the first quarter of 2019 to reduce the goodwill to $0 for the Statia Bunkering reporting unit.
The impairment charges are included in “Loss from discontinued operations, net of tax” on the consolidated statement of loss for the year ended December 31, 2019.
Discontinued Operations. During the second quarter of 2019, we determined the assets and liabilities associated with the St. Eustatius Operations met the criteria to be classified as held for sale. We determined the St. Eustatius Operations met the requirements to be reported as discontinued operations since the St. Eustatius Disposition and the sale of the European operations in November 2018 together represented a strategic shift that will have a major impact on our operations and financial results. These sales were part of our plan to improve our debt metrics and partially fund capital projects to grow our core business in North America. Accordingly, we reclassified certain balances to assets held for sale and liabilities held for sale. The consolidated statement of loss for the year ended December 31, 2019 reflects the St. Eustatius Operations as discontinued operations.
The following is a reconciliation of the major classes of line items included in “Loss from discontinued operations, net of tax” on the consolidated statements of income (loss):
| Year Ended December 31, 2019 | |||||
| (Thousands of Dollars) | |||||
| Revenues | $ | ||||
| Costs and expenses: | |||||
| Cost of revenues | |||||
| Impairment losses | |||||
| General and administrative expenses (excluding depreciation and amortization expense) | |||||
| Total costs and expenses | |||||
| Operating loss | ( | ||||
| Interest income, net | |||||
| Other expense, net | ( | ||||
| Loss from discontinued operations before income tax expense | ( | ||||
| Income tax expense | |||||
| Loss from discontinued operations, net of tax | $ | ( | |||
The consolidated statements of cash flows have not been adjusted to separately disclose cash flows related to discontinued operations. The following table presents selected cash flow information associated with our discontinued operations:
| Year Ended December 31, 2019 | |||||
| (Thousands of Dollars) | |||||
| Capital expenditures | $ | ( | |||
| Significant noncash operating activities and other adjustments: | |||||
| Depreciation and amortization expense | $ | ||||
| Asset impairment losses | $ | ||||
| Goodwill impairment loss | $ | ||||
| Loss from sale of the St. Eustatius Operations | $ | ||||
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5. REVENUE FROM CONTRACTS WITH CUSTOMERS
Contract Assets and Contract Liabilities
The following table provides information about contract assets and contract liabilities from contracts with customers:
| 2021 | 2020 | 2019 | |||||||||||||||||||||||||||||||||
| Contract Assets | Contract Liabilities | Contract Assets | Contract Liabilities | Contract Assets | Contract Liabilities | ||||||||||||||||||||||||||||||
| (Thousands of Dollars) | |||||||||||||||||||||||||||||||||||
| Balances as of January 1: | |||||||||||||||||||||||||||||||||||
| Current portion | $ | $ | ( | $ | $ | ( | $ | $ | ( | ||||||||||||||||||||||||||
| Noncurrent portion | ( | ( | ( | ||||||||||||||||||||||||||||||||
| Held for sale | ( | ||||||||||||||||||||||||||||||||||
| Total | ( | ( | ( | ||||||||||||||||||||||||||||||||
| Activity: | |||||||||||||||||||||||||||||||||||
| Additions | ( | ( | ( | ||||||||||||||||||||||||||||||||
| Transfer to accounts receivable | ( | — | ( | — | ( | — | |||||||||||||||||||||||||||||
| Transfer to revenues, including amounts reported in discontinued operations | ( | ( | |||||||||||||||||||||||||||||||||
| Total | ( | ( | |||||||||||||||||||||||||||||||||
| Balances as of December 31: | |||||||||||||||||||||||||||||||||||
| Current portion | ( | ( | ( | ||||||||||||||||||||||||||||||||
| Noncurrent portion | ( | ( | ( | ||||||||||||||||||||||||||||||||
| Total | $ | $ | ( | $ | $ | ( | $ | $ | ( | ||||||||||||||||||||||||||
Contract assets relate to performance obligations satisfied in advance of scheduled billings. Current contract assets are included in “Other current assets” and noncurrent contract assets are included in “Other long-term assets, net” on the consolidated balance sheets. Contract liabilities relate to payments received in advance of satisfying performance obligations under a contract, which mainly result from contracts with an incentive pricing structure, CIAC payments and contracts with MVCs. The current portion of contract liabilities are included in “Accrued liabilities” and the noncurrent portion of contract liabilities are included in “Other long-term liabilities” on the consolidated balance sheets.
Remaining Performance Obligations
The following table presents our estimated revenue from contracts with customers for remaining performance obligations that has not yet been recognized, representing our contractually committed revenue as of December 31, 2021 (in thousands of dollars):
| 2022 | $ | |||||||
| 2023 | ||||||||
| 2024 | ||||||||
| 2025 | ||||||||
| 2026 | ||||||||
| Thereafter | ||||||||
| Total | $ | |||||||
Our contractually committed revenue, for purposes of the tabular presentation above, is generally limited to customer contracts that have fixed pricing and fixed volume terms and conditions, generally including contracts with MVC payment obligations.
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
Disaggregation of Revenues
The following table disaggregates our revenues:
| Year Ended December 31, | |||||||||||||||||
| 2021 | 2020 | 2019 | |||||||||||||||
| (Thousands of Dollars) | |||||||||||||||||
| Pipeline segment: | |||||||||||||||||
| Crude oil pipelines | $ | $ | $ | ||||||||||||||
| Refined products and ammonia pipelines (excluding lessor revenues) | |||||||||||||||||
| Total pipeline segment revenues from contracts with customers | |||||||||||||||||
| Lessor revenues | |||||||||||||||||
| Total pipeline segment revenues | |||||||||||||||||
| Storage segment: | |||||||||||||||||
| Throughput terminals | |||||||||||||||||
| Storage terminals (excluding lessor revenues) | |||||||||||||||||
| Total storage segment revenues from contracts with customers | |||||||||||||||||
| Lessor revenues | |||||||||||||||||
| Total storage segment revenues | |||||||||||||||||
| Fuels marketing segment: | |||||||||||||||||
| Revenues from contracts with customers | |||||||||||||||||
| Consolidation and intersegment eliminations | ( | ( | ( | ||||||||||||||
| Total revenues | $ | $ | $ | ||||||||||||||
6. ALLOWANCE FOR CREDIT LOSSES
The balance of and changes in the allowance for credit losses consisted of the following:
| Year Ended December 31, | |||||||||||
| 2020 | 2019 | ||||||||||
| (Thousands of Dollars) | |||||||||||
| Balance as of beginning of year | $ | $ | |||||||||
| Current period provision for credit losses | |||||||||||
| Write-offs charged against the allowance | ( | ( | |||||||||
| Balance as of end of year | $ | $ | |||||||||
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
7. INVENTORIES
Inventories consisted of the following:
| December 31, | |||||||||||
| 2021 | 2020 | ||||||||||
| (Thousands of Dollars) | |||||||||||
| Petroleum products | $ | $ | |||||||||
| Materials and supplies | |||||||||||
| Total | $ | $ | |||||||||
We purchase petroleum products for resale. Our petroleum products consist of intermediates, gasoline, distillates and other petroleum products. Materials and supplies mainly consist of blending and additive chemicals and maintenance materials used in our pipeline and storage segments.
8. PROPERTY, PLANT AND EQUIPMENT
Property, plant and equipment consisted of the following:
| Estimated Useful Lives | December 31, | ||||||||||||||||||||||
| 2021 | 2020 | ||||||||||||||||||||||
| (Years) | (Thousands of Dollars) | ||||||||||||||||||||||
| Land, buildings and improvements | - | $ | $ | ||||||||||||||||||||
| Pipelines, storage and terminals | - | ||||||||||||||||||||||
| Rights-of-way | - | ||||||||||||||||||||||
| Construction in progress | |||||||||||||||||||||||
| Total | |||||||||||||||||||||||
| Less accumulated depreciation and amortization | ( | ( | |||||||||||||||||||||
| Property, plant and equipment, net | $ | $ | |||||||||||||||||||||
Capitalized interest costs added to property, plant and equipment, including amounts related to discontinued operations, totaled $3.9 million, $4.9 million and $8.9 million for the years ended December 31, 2021, 2020 and 2019, respectively. Depreciation and amortization expense for property, plant and equipment totaled $220.4 million, $228.8 million and $226.0 million for the years ended December 31, 2021, 2020 and 2019, respectively, including depreciation and amortization expense reported in “Loss from discontinued operations, net of tax” on the consolidated statements of income (loss).
9. INTANGIBLE ASSETS
Intangible assets consisted of the following:
| Weighted-Average Amortization Period | December 31, 2021 | December 31, 2020 | |||||||||||||||||||||||||||
| Cost | Accumulated Amortization | Cost | Accumulated Amortization | ||||||||||||||||||||||||||
| (Years) | (Thousands of Dollars) | ||||||||||||||||||||||||||||
| Customer contracts and relationships | $ | $ | ( | $ | $ | ( | |||||||||||||||||||||||
| Other | ( | ( | |||||||||||||||||||||||||||
| Total | $ | $ | ( | $ | $ | ( | |||||||||||||||||||||||
Intangible assets are recorded at fair value as of the date acquired. All of our intangible assets are amortized on a straight-line basis. Amortization expense for intangible assets was $48.5 million for the year ended December 31, 2021 and $51.4 44.0 million for 2022 and $38.0
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
10. GOODWILL
The balances of and changes in the carrying amount of goodwill by segment were as follows:
| Pipeline | Storage | Total | |||||||||||||||
| (Thousands of Dollars) | |||||||||||||||||
| Balances as of January 1, 2020 | $ | $ | $ | ||||||||||||||
| Activity for the year ended December 31, 2020: | |||||||||||||||||
| Goodwill impairment loss on crude oil pipelines | ( | ( | |||||||||||||||
| Texas City Sale | ( | ( | |||||||||||||||
| Balances as of December 31, 2020: | |||||||||||||||||
| Goodwill | |||||||||||||||||
| Accumulated impairment loss | ( | ( | |||||||||||||||
| Net goodwill | |||||||||||||||||
| Activity for the year ended December 31, 2021: | |||||||||||||||||
| Goodwill impairment loss on Eastern U.S. Terminal Operations | ( | ( | |||||||||||||||
| Balances as of December 31, 2021: | |||||||||||||||||
| Goodwill | |||||||||||||||||
| Accumulated impairment loss | ( | ( | |||||||||||||||
| Net goodwill | $ | $ | $ | ||||||||||||||
Eastern U.S. Terminals Operations. On October 8, 2021, we completed the sale of the Eastern U.S. Terminals Operations. In the third quarter of 2021, the Eastern U.S. Terminal Operations met the criteria to be classified as held for sale, and we tested the allocated goodwill for impairment. We recognized a goodwill impairment charge of $34.1 million in the third quarter of 2021. Please see Note 4 for additional information on the disposition.
Texas City Sale. On December 7, 2020, we completed the Texas City Sale and the goodwill associated with the sold terminals was included in the calculation of the loss on sale. Please see Note 4 for additional information on the sale.
2020 Impairment. In March 2020, the COVID-19 pandemic and actions taken by the Organization of Petroleum Exporting Countries and other oil-producing nations (OPEC+) resulted in severe disruptions in the capital and commodities markets, which led to significant decline in our unit price. As a result, our equity market capitalization fell significantly. The decline in crude oil prices and demand for petroleum products also led to a decline in expected earnings from some of our goodwill reporting units. These factors and others related to COVID-19 and OPEC+ caused us to conclude there were triggering events that occurred in March 2020 that required us to perform a goodwill impairment test as of March 31, 2020. We recognized a goodwill impairment charge of $225.0 million in the first quarter of 2020, which is reported in the pipeline segment. Our assessment did not identify any other reporting units at risk of a goodwill impairment.
We calculated the estimated fair value of each of our reporting units using a weighted-average of values determined from an income approach and a market approach. The income approach involves estimating the fair value of each reporting unit by discounting its estimated future cash flows using a discount rate that would be consistent with a market participant’s assumption. The market approach bases the fair value measurement on information obtained from observed stock prices of public companies and recent merger and acquisition transaction data of comparable entities. In order to estimate the fair value of goodwill, management must make certain estimates and assumptions that affect the total fair value of the reporting unit including, among other things, an assessment of market conditions, projected cash flows, discount rates and growth rates. Management’s estimates of projected cash flows related to the reporting unit include, but are not limited to, future earnings of the reporting unit, assumptions about the use or disposition of assets included in the reporting unit, estimated remaining lives of those assets, and future expenditures necessary to maintain the assets’ existing service potential. The assumptions in the fair value measurement reflect the current market environment, industry-specific factors and company-specific factors.
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The decline in expected earnings from certain of our long-lived assets was also an indicator that the carrying values of these long-lived assets may not be recoverable. Prior to performing the goodwill impairment test, we tested these long-lived assets for recoverability and determined they were fully recoverable as of March 31, 2020.
Management’s estimates are based on numerous assumptions about future operations and market conditions, which we believe to be reasonable but are inherently uncertain. The uncertainties underlying our assumptions and estimates could differ significantly from actual results, including with respect to the duration and severity of the COVID-19 pandemic.
11. ACCRUED LIABILITIES
Accrued liabilities consisted of the following:
| December 31, | |||||||||||
| 2021 | 2020 | ||||||||||
| (Thousands of Dollars) | |||||||||||
| Employee wages and benefit costs | $ | $ | |||||||||
| Revenue contract liabilities | |||||||||||
| Operating lease liabilities | |||||||||||
| Environmental costs | |||||||||||
| Other | |||||||||||
| Accrued liabilities | $ | $ | |||||||||
12. DEBT
Short-term debt consisted of the current portion of finance leases, with balances of $3.8 million as of December 31, 2021 and 2020. Please refer to Note 15 for additional information.
Long-term debt consisted of the following:
| December 31, | |||||||||||||||||||||||
| Maturity | 2021 | 2020 | |||||||||||||||||||||
| (Thousands of Dollars) | |||||||||||||||||||||||
| Revolving Credit Agreement | April 27, 2025 (a) | $ | $ | ||||||||||||||||||||
| 6.75% senior notes | February 1, 2021 | — | |||||||||||||||||||||
| 4.75% senior notes | February 1, 2022 | — | |||||||||||||||||||||
| 5.75% senior notes | October 1, 2025 | ||||||||||||||||||||||
| 6.00% senior notes | June 1, 2026 | ||||||||||||||||||||||
| 5.625% senior notes | April 28, 2027 | ||||||||||||||||||||||
| 6.375% senior notes | October 1, 2030 | ||||||||||||||||||||||
| Subordinated Notes | January 15, 2043 | ||||||||||||||||||||||
| GoZone Bonds | 2038 | thru | 2041 | ||||||||||||||||||||
| Receivables Financing Agreement | January 31, 2025 (a) | ||||||||||||||||||||||
| Net fair value adjustments, unamortized discounts and unamortized debt issuance costs | N/A | ( | ( | ||||||||||||||||||||
| Total long-term debt (excluding finance leases) | |||||||||||||||||||||||
Finance leases (refer to Note 15) | |||||||||||||||||||||||
| Long-term debt, less current portion | $ | $ | |||||||||||||||||||||
(a)On January 28, 2022, the maturity date on the Revolving Credit Agreement was extended from October 27, 2023 to April 27, 2025 and the scheduled termination date of the Receivables Financing Agreement was extended from September 20, 2023 to January 31, 2025.
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The long-term debt repayments (excluding finance leases) as of December 31, 2021 are due as follows (in thousands of dollars):
| 2022 | $ | ||||
| 2023 (a) | |||||
| 2024 | |||||
| 2025 | |||||
| 2026 | |||||
| Thereafter | |||||
| Total repayments | |||||
| Net fair value adjustments, unamortized discounts and unamortized debt issuance costs | ( | ||||
| Total long-term debt (excluding finance leases) | $ | ||||
(a)On January 28, 2022, the maturity date on the Revolving Credit Agreement was extended from October 27, 2023 to April 27, 2025 and the scheduled termination date of the Receivables Financing Agreement was extended from September 20, 2023 to January 31, 2025.
Interest payments totaled $220.0 million, $207.2 million and $183.8 million for the years ended December 31, 2021, 2020 and 2019, respectively, related to debt obligations. We amortized an aggregate of $7.9 million, $11.4 million and $6.5 million of debt issuance costs and debt discount combined for the years ended December 31, 2021, 2020 and 2019, respectively.
Revolving Credit Agreement
As of December 31, 2021, NuStar Logistics’ $1.0 billion revolving credit agreement (the Revolving Credit Agreement) had $884.8 million available for borrowing and $110.5 million borrowings outstanding. Letters of credit issued under the Revolving Credit Agreement totaled $4.7 million as of December 31, 2021. Letters of credit limit the amount we can borrow under the Revolving Credit Agreement. Obligations under the Revolving Credit Agreement are guaranteed by NuStar Energy and NuPOP.
Prior to the amendment on January 28, 2022, described below, the Revolving Credit Agreement bore interest, at our option, based on an alternative base rate or a LIBOR-based rate. The interest rate on the Revolving Credit Agreement is subject to adjustment if our debt rating is downgraded (or upgraded) by certain credit rating agencies. In August of 2020, Moody’s Investor Service Inc. downgraded our credit rating from Ba2 to Ba3. This rating downgrade caused the interest rate on our Revolving Credit Agreement to increase by 0.25% effective August 2020. The interest rate on the Revolving Credit Agreement and certain fees under the Receivables Financing Agreement, defined below, are the only debt arrangements that are subject to adjustment if our debt rating is downgraded (or upgraded) by certain credit rating agencies. As of December 31, 2021, our weighted-average interest rate under our Revolving Credit Agreement was 2.9 %. During the year ended December 31, 2021, the weighted-average interest rate related to borrowings under the Revolving Credit Agreement was 2.7 %.
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Notes
NuStar Logistics Senior Notes. On November 1, 2021, we repaid our $250.0 million of 4.75 % senior notes due February 1, 2022 with proceeds from the Eastern U.S. Terminals Disposition. We repaid our $300.0 million of 6.75 % senior notes due February 1, 2021 and our $450.0 million of 4.8 % senior notes due September 1, 2020 with borrowings under our Revolving Credit Agreement.
On September 14, 2020, NuStar Logistics issued $600.0 million of 5.75 % senior notes due October 1, 2025 and $600.0 million of 6.375 % senior notes due October 1, 2030. We received proceeds of $1,182.0 million, net of issuance costs of $18.0 million, which we used to repay outstanding borrowings and the early repayment premiums under the Term Loan, as defined below, as well as outstanding borrowings under our Revolving Credit Agreement. The issuance of the 5.75 % and 6.375 % senior notes bolstered our liquidity to address our senior note maturities that we repaid in 2021. On May 22, 2019, NuStar Logistics issued $500.0 million of 6.0 % senior notes due June 1, 2026. We received net proceeds of $491.6 million, which we used to repay outstanding borrowings under our Revolving Credit Agreement.
Interest is payable semi-annually in arrears for the $600.0 million of 5.75 % senior notes, $500.0 million of 6.0 % senior notes, $550.0 million of 5.625 % senior notes and $600.0 million of 6.375 % senior notes (collectively, the NuStar Logistics Senior Notes).
The NuStar Logistics Senior Notes do not have sinking fund requirements. These notes rank equally with existing senior unsecured indebtedness and senior to existing subordinated indebtedness of NuStar Logistics and contain restrictions on NuStar Logistics’ ability to incur secured indebtedness unless the same security is also provided for the benefit of holders of the NuStar Logistics Senior Notes. In addition, the NuStar Logistics Senior Notes limit the ability of NuStar Logistics and its subsidiaries to, among other things, incur indebtedness secured by certain liens, engage in certain sale-leaseback transactions and engage in certain consolidations, mergers or asset sales. At the option of NuStar Logistics, the NuStar Logistics Senior Notes may be redeemed in whole or in part at any time at a redemption price, plus accrued and unpaid interest to the redemption date. If we undergo a change of control, as defined in the supplemental indentures for the NuStar Logistics Senior Notes, each holder of the applicable senior notes may require us to repurchase all or a portion of its notes at a price equal to 101% of the principal amount of the notes repurchased, plus any accrued and unpaid interest to the date of repurchase.
NuStar Logistics Subordinated Notes. NuStar Logistics’ $402.5 million of fixed-to-floating rate subordinated notes are due January 15, 2043 (the Subordinated Notes). The Subordinated Notes are fully and unconditionally guaranteed on an unsecured and subordinated basis by NuStar Energy and NuPOP. Effective January 15, 2018, the interest rate on the Subordinated Notes switched to an annual rate equal to the sum of the three-month LIBOR for the related quarterly interest period, plus 6.734% payable quarterly, commencing April 15, 2018, unless payment is deferred in accordance with the terms of the notes. NuStar Logistics may elect to defer interest payments on the Subordinated Notes on one or more occasions for up to five consecutive years. Deferred interest will accumulate additional interest at a rate equal to the interest rate then applicable to the Subordinated Notes until paid. If NuStar Logistics elects to defer interest payments, NuStar Energy cannot declare or make cash distributions to its unitholders during the period that interest payments are deferred. As of December 31, 2021, the interest rate was 6.9 %.
The Subordinated Notes do not have sinking fund requirements and are subordinated to existing senior unsecured indebtedness of NuStar Logistics and NuPOP. The Subordinated Notes do not contain restrictions on NuStar Logistics’ ability to incur additional indebtedness, including debt that ranks senior in priority of payment to the notes. In addition, the Subordinated Notes do not limit NuStar Logistics’ ability to incur indebtedness secured by liens or to engage in certain sale-leaseback transactions. Effective January 15, 2018, we may redeem the Subordinated Notes in whole or in part at a redemption price equal to 100 % of the principal amount plus accrued and unpaid interest to the redemption date.
Gulf Opportunity Zone Revenue Bonds
In 2008, 2010 and 2011, the Parish of St. James, Louisiana issued Revenue Bonds Series 2008, Series 2010, Series 2010A, Series 2010B and Series 2011 associated with our St. James terminal expansions pursuant to the Gulf Opportunity Zone Act of 2005 for an aggregate $365.4 million (collectively, the GoZone Bonds). Following the issuances, the proceeds were deposited with a trustee and were disbursed to us upon our request for reimbursement of expenditures related to our St. James terminal. On March 4, 2020, NuStar Logistics repaid $43.3 million of GoZone Bonds with unused funds, which had been held in trust. NuStar Logistics is obligated to make payments in amounts sufficient to pay the principal of, premium, if any, interest and certain other payments on, the GoZone Bonds.
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NUSTAR ENERGY L.P. AND SUBSIDIARIES
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On June 3, 2020, NuStar Logistics completed the reoffering and conversion of the GoZone Bonds through supplements to the original indentures governing the GoZone Bonds and supplements to the original agreements between NuStar Logistics and the Parish of St. James, which, among other things, converted the interest rate from a weekly rate to a long-term rate. In connection with the reoffering and conversion, we terminated the letters of credit previously issued by various individual banks on our behalf to support the payments required in connection with the GoZone Bonds, and NuStar Energy and NuPOP guaranteed NuStar Logistics’ obligations with respect to the GoZone Bonds. We did not receive any proceeds from the reoffering, and the reoffering did not increase our outstanding debt.
The following table summarizes the GoZone Bonds outstanding as of December 31, 2021:
| Series | Date Issued | Amount Outstanding | Interest Rate | Mandatory Purchase Date | Maturity Date | |||||||||||||||||||||||||||
| (Thousands of Dollars) | ||||||||||||||||||||||||||||||||
| Series 2008 | $ | % | June 1, 2030 | |||||||||||||||||||||||||||||
| Series 2010 | % | n/a | ||||||||||||||||||||||||||||||
| Series 2010A | % | n/a | ||||||||||||||||||||||||||||||
| Series 2010B | % | June 1, 2030 | ||||||||||||||||||||||||||||||
| Series 2011 | % | June 1, 2025 | ||||||||||||||||||||||||||||||
| Total | $ | |||||||||||||||||||||||||||||||
Interest on the GoZone Bonds accrues from June 3, 2020 and is payable semi-annually on June 1 and December 1 of each year, beginning December 1, 2020. The holders of the Series 2008, Series 2010B and Series 2011 GoZone Bonds are required to tender their bonds at the applicable mandatory purchase date in exchange for 100% of the principal plus accrued and unpaid interest, after which these bonds will potentially be remarketed with a new interest rate established. Each of the Series 2010 and Series 2010A GoZone Bonds is subject to redemption on or after June 1, 2030 by the Parish of St. James, at our option, in whole or in part, at a redemption price of 100% of the principal amount to be redeemed plus accrued interest. The Series 2008, Series 2010B and Series 2011 GoZone Bonds are not subject to optional redemption.
NuStar Logistics’ agreements with the Parish of St. James related to the GoZone Bonds contain (i) customary restrictive covenants that limit the ability of NuStar Logistics and its subsidiaries, to, among other things, create liens or enter into sale-leaseback transactions, consolidations, mergers or asset sales and (ii) a change of control provision that provides each holder the right to require the trustee, with funds provided by NuStar Logistics, to repurchase all or a portion of that holder’s GoZone Bonds upon a change of control at a price equal to 101% of the aggregate principal amount repurchased, plus any accrued and unpaid interest.
Receivables Financing Agreement
NuStar Energy and NuStar Finance LLC (NuStar Finance), a special purpose entity and wholly owned subsidiary of NuStar Energy, are parties to a $100.0 million receivables financing agreement with a third-party lender (the Receivables Financing Agreement) and agreements with certain of NuStar Energy’s wholly owned subsidiaries (together with the Receivables Financing Agreement, the Securitization Program). Under the Securitization Program, certain of NuStar Energy’s wholly owned subsidiaries (collectively, the Originators), sell their accounts receivable to NuStar Finance on an ongoing basis, and NuStar Finance provides the newly acquired accounts receivable as collateral for its revolving borrowings under the Receivables Financing Agreement. NuStar Energy provides a performance guarantee in connection with the Securitization Program. The amount available for borrowing is based on the availability of eligible receivables and other customary factors and conditions. The Securitization Program contains various customary affirmative and negative covenants and default, indemnification and termination provisions, and the Receivables Financing Agreement provides for acceleration of amounts owed upon the occurrence of certain specified events. NuStar Finance’s sole activity consists of purchasing such receivables and providing them as collateral under the Securitization Program. NuStar Finance is a separate legal entity and the assets of NuStar Finance, including these accounts receivable, are not available to satisfy the claims of creditors of NuStar Energy, the Originators or their affiliates.
On January 28, 2022, the Receivables Financing Agreement was amended to, among other things: (i) extend the scheduled termination date from September 20, 2023 to January 31, 2025; (ii) reduce the floor rate in the calculation of our borrowing rates; and (iii) replace provisions related to the LIBOR rate of interest with references to SOFR rates of interest. On September 3, 2020, the Receivables Financing Agreement was amended to, among other things: (i) reduce the amount available for borrowing from $125.0 million to $100.0 million, (ii) provide that the failure to satisfy the consolidated debt coverage ratio, as
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
defined in the Revolving Credit Agreement, would constitute an Event of Default as defined in the Receivables Financing Agreement, and (iii) increase the interest rate.
Prior to the January 28, 2022 amendment described above, borrowings by NuStar Finance under the Receivables Financing Agreement bore interest at the applicable bank rate, as defined under the Receivables Financing Agreement. Following the amendment, borrowings under the Receivables Financing Agreement bear interest, at NuStar Finance’s option, at a base rate or a SOFR rate, each as defined in the Receivables Financing Agreement. As of December 31, 2021 and 2020, accounts receivable totaling $119.2 million and $110.6 million, respectively, were included in the Securitization Program. The weighted average interest rate related to outstanding borrowings under the Securitization Program during the year ended December 31, 2021 was 2.3 %.
Term Loan Credit Agreement
On April 19, 2020, NuStar Energy and NuStar Logistics entered into an unsecured term loan credit agreement with certain lenders and Oaktree Fund Administration, LLC, as administrative agent for the lenders. The Term Loan provided for an aggregate commitment of up to $750.0 million pursuant to a three-year unsecured term loan credit facility. NuStar Logistics drew $500.0 million (the Initial Loan) on April 21, 2020 (the Initial Loan Funding Date). We utilized the proceeds from the Initial Loan, net of the original issue discount of $22.5 million (3.0 % of the total commitment) and issuance costs of $14.4 million, to repay outstanding borrowings under our Revolving Credit Agreement. The Term Loan bolstered our liquidity to address near-term senior note maturities.
On September 16, 2020, we used a portion of the net proceeds from the issuance of the 5.75 % and 6.375 % senior notes to repay the $500.0 million of outstanding borrowings under the Term Loan and pay related early repayment premiums totaling $97.6 million. We also recognized costs of $40.3 million related to unamortized debt issuance costs, unamortized discount and a commitment fee, which resulted in a loss from extinguishment of debt of $137.9 million in the third quarter of 2020. On February 16, 2021, we terminated the Term Loan.
Outstanding borrowings bore interest at an aggregate rate of 12.0 % per annum, and the Term Loan was subject to a commitment fee in the amount of 5.0 % per annum on the average daily undrawn amount of $250.0 million until April 19, 2021.
13. HEALTH, SAFETY AND ENVIRONMENTAL MATTERS
Our operations are subject to extensive international, federal, state and local environmental laws and regulations, in the U.S. and in the other countries in which we operate, including those relating to the discharge of materials into the environment, waste management, remediation, the characteristics and composition of fuels, climate change and greenhouse gases. Our operations are also subject to extensive health, safety and security laws and regulations, including those relating to worker and pipeline safety, pipeline and storage tank integrity and operations security. The principal environmental, health, safety and security risks associated with our operations relate to unauthorized emissions into the air, releases into soil, surface water or groundwater, personal injury and property damage. We have adopted policies, practices, systems and procedures designed to comply with the laws and regulations, and to help minimize and mitigate these risks, limit the liability that could result from such events, prevent material environmental or other damage, ensure the safety of our employees and the public and secure our pipelines, terminals and operations. Compliance with environmental, health, safety and security laws, regulations and related permits increases our capital expenditures and operating expenses, and violation of these laws, regulations or permits could result in significant civil and criminal liabilities, injunctions or other penalties. Future governmental action and regulatory initiatives could result in more restrictive laws and regulations, which could increase required capital expenditures and operating expenses. The risk of additional compliance expenditures, expenses and liabilities are inherent to government-regulated industries, including midstream energy. As a result, there can be no assurances that significant expenditures, expenses and liabilities will not be incurred in the future.
Most of our pipelines are subject to federal regulation by one or more of the following governmental agencies: the Federal Energy Regulatory Commission (the FERC), the Surface Transportation Board (the STB), the Department of Transportation (DOT), the Environmental Protection Agency (EPA) and the Department of Homeland Security. Additionally, our pipelines are subject to the respective jurisdictions of the states those lines traverse.
Environmental and safety exposures and liabilities are difficult to assess and estimate due to unknown factors such as the timing and extent of remediation, the determination of our liability in proportion to other parties, improvements in cleanup technologies and the extent to which environmental and safety laws and regulations may change in the future. Although environmental and safety costs may have a significant impact on the results of operations for any single period, we believe that such costs will not have a material adverse effect on our financial position.
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
The balance of and changes in the accruals for environmental matters were as follows:
| Year Ended December 31, | |||||||||||
| 2021 | 2020 | ||||||||||
| (Thousands of Dollars) | |||||||||||
| Balance as of the beginning of year | $ | $ | |||||||||
| Additions to accrual | |||||||||||
| Payments | ( | ( | |||||||||
| Balance as of the end of year | $ | $ | |||||||||
Accruals for environmental matters are included in the consolidated balance sheets as follows:
| December 31, | |||||||||||
| 2021 | 2020 | ||||||||||
| (Thousands of Dollars) | |||||||||||
| Accrued liabilities | $ | $ | |||||||||
| Other long-term liabilities | |||||||||||
| Accruals for environmental matters | $ | $ | |||||||||
14. COMMITMENTS, CONTINGENCIES AND UNCERTAINTIES
Commitments
Future minimum rental payments applicable to all noncancellable purchase obligations as of December 31, 2021 are as follows:
| Payments Due by Period | |||||||||||||||||||||||||||||||||||||||||
| 2022 | 2023 | 2024 | 2025 | 2026 | Thereafter | Total | |||||||||||||||||||||||||||||||||||
| (Thousands of Dollars) | |||||||||||||||||||||||||||||||||||||||||
| Purchase obligations | $ | $ | $ | $ | $ | $ | $ | ||||||||||||||||||||||||||||||||||
Contingencies
We have contingent liabilities resulting from various litigation, claims and commitments. We record accruals for loss contingencies when losses are considered probable and can be reasonably estimated. Legal fees associated with defending the Partnership in legal matters are expensed as incurred. We accrued $0.1 million and $2.6 million for contingent losses as of December 31, 2021 and 2020, respectively. The amount that will ultimately be paid related to such matters may differ from the recorded accruals, and the timing of such payments is uncertain. We evaluate each contingent loss at least quarterly, and more frequently as each matter progresses and develops over time, and we do not believe that the resolution of any particular claim or proceeding, or all matters in the aggregate, would have a material adverse effect on our results of operations, financial position or liquidity.
Uncertainties
The coronavirus, or COVID-19, had a severe negative impact on global economic activity during 2020, significantly reducing demand for petroleum products and increasing the volatility of crude oil prices, beginning in March 2020. While the U.S. economy has demonstrated signs of stabilization and improvement in 2021, ongoing uncertainty surrounding the COVID-19 pandemic has caused and may continue to cause volatility and could have a significant impact on management’s estimates and assumptions in 2022 and beyond.
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
15. LEASE ASSETS AND LIABILITIES
Lessee Arrangements
Right-of-use assets and lease liabilities included in our consolidated balance sheet were as follows:
| December 31, | ||||||||||||||||||||
| Balance Sheet Location | 2021 | 2020 | ||||||||||||||||||
| (Thousands of Dollars) | ||||||||||||||||||||
| Right-of-Use Assets: | ||||||||||||||||||||
| Operating | Other long-term assets, net | $ | $ | |||||||||||||||||
| Finance | Property, plant and equipment, net of accumulated amortization of $ | $ | $ | |||||||||||||||||
| Lease Liabilities: | ||||||||||||||||||||
| Operating: | ||||||||||||||||||||
| Current | Accrued liabilities | $ | $ | |||||||||||||||||
| Noncurrent | Other long-term liabilities | |||||||||||||||||||
| Total operating lease liabilities | $ | $ | ||||||||||||||||||
| Finance: | ||||||||||||||||||||
| Current | Current portion of finance lease obligations | $ | $ | |||||||||||||||||
| Noncurrent | Long-term debt, less current portion | |||||||||||||||||||
| Total finance lease liabilities | $ | $ | ||||||||||||||||||
As of December 31, 2021, maturities of our operating and finance lease liabilities were as follows:
| Operating Leases | Finance Leases | |||||||||||||
| (Thousands of Dollars) | ||||||||||||||
| 2022 | $ | $ | ||||||||||||
| 2023 | ||||||||||||||
| 2024 | ||||||||||||||
| 2025 | ||||||||||||||
| 2026 | ||||||||||||||
| Thereafter | ||||||||||||||
| Total lease payments | $ | $ | ||||||||||||
| Less: Interest | ||||||||||||||
| Present value of lease liabilities | $ | $ | ||||||||||||
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NUSTAR ENERGY L.P. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
Costs incurred for leases, including costs associated with discontinued operations, were as follows:
| Year Ended December 31, | ||||||||||||||||||||
| 2021 | 2020 | 2019 | ||||||||||||||||||
| (Thousands of Dollars) | ||||||||||||||||||||
| Operating lease cost | $ | $ | $ | |||||||||||||||||
| Finance lease cost: | ||||||||||||||||||||
| Amortization of right-of-use assets | $ | $ | $ | |||||||||||||||||
| Interest expense on lease liability | $ | $ | $ | |||||||||||||||||
| Short-term lease cost | $ | $ | $ | |||||||||||||||||
| Variable lease cost | $ | $ | $ | |||||||||||||||||
| Total lease cost | $ | $ | $ | |||||||||||||||||
The table below presents additional information regarding our leases.
| 2021 | 2020 | 2019 | |||||||||||||||||||||||||||||||||
| Operating Leases | Finance Leases | Operating Leases | Finance Leases | Operating Leases | Finance Leases | ||||||||||||||||||||||||||||||
| (Thousands of Dollars, Except Term and Rate Data) | |||||||||||||||||||||||||||||||||||
| For the year ended December 31: | |||||||||||||||||||||||||||||||||||
| Cash outflows from operating activities | $ | $ | $ | $ | $ | $ | |||||||||||||||||||||||||||||
| Cash outflows from financing activities | $ | — | $ | $ | — | $ | $ | — | $ | ||||||||||||||||||||||||||
| Right-of-use assets obtained in exchange for lease liabilities | $ | $ | $ | $ | $ | $ | |||||||||||||||||||||||||||||
| As of December 31: | |||||||||||||||||||||||||||||||||||
| Weighted-average remaining lease term (in years) | |||||||||||||||||||||||||||||||||||
| Weighted-average discount rate | % | % | % | % | % | % | |||||||||||||||||||||||||||||
Lessor Arrangements
We have entered into certain revenue arrangements where we are considered to be the lessor. Under the largest of these arrangements, we lease certain of our storage tanks in exchange for a fixed fee, subject to an annual consumer price index adjustment. The operating leases commenced on January 1, 2017, and have initial terms of 10 years with successive automatic renewal terms. We recognized lease revenues from these leases of $41.5 million, $41.3 million, and $40.8 million for the years ended December 31, 2021, 2020, and 2019, respectively, which are included in “Service revenues” in the consolidated statements of income (loss). As of December 31, 2021, we expect to receive minimum lease payments totaling $195.6 million, based upon the consumer price index as of the adoption date. We will recognize these payments ratably over the remaining initial lease term.
The table below presents cost, accumulated depreciation and useful life information related to our storage lease assets, which are included in our “Pipeline, storage and terminals” asset class within property, plant and equipment:
| Estimated Useful Life | December 31, | ||||||||||||||||
| 2021 | 2020 | ||||||||||||||||
| (Years) | (Thousands of Dollars) | ||||||||||||||||
| Lease storage assets, at cost | $ | $ | |||||||||||||||
| Less accumulated depreciation | ( | ( | |||||||||||||||
| Lease storage assets, net | $ | $ | |||||||||||||||
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
16. DERIVATIVES AND FAIR VALUE MEASUREMENTS
Derivative Instruments
We utilize various derivative instruments to manage our exposure to interest rate risk and commodity price risk. Our risk management policies and procedures are designed to monitor interest rates, futures and swap positions and over-the-counter positions, as well as physical commodity volumes, grades, locations and delivery schedules, to help ensure that our hedging activities address our market risks.
Commodity Price Risk. The results of operations for the fuels marketing segment depend largely on the margin between our cost and the sales prices of the products we market. Therefore, the results of operations for this segment are more sensitive to changes in commodity prices compared to the operations of the pipeline and storage segments. Since our fuels marketing operations expose us to commodity price risk, we enter into derivative instruments to mitigate the effect of commodity price fluctuations on our operations. Derivative financial instruments associated with commodity price risk with respect to our petroleum product inventories and related firm commitments to purchase and/or sell such inventories were not material for any period presented.
Interest Rate Risk. We were a party to certain interest rate swap agreements to manage our exposure to changes in interest rates, which consisted of forward-starting interest rate swap agreements related to forecasted debt issuances. We entered into these swaps in order to hedge the risk of fluctuations in the required interest payments attributable to changes in the benchmark interest rate during the period from the effective date of the swap to the issuance of the forecasted debt. Under the terms of the swaps, we paid a weighted-average fixed rate and received a rate based on the three-month USD LIBOR . These swaps qualified as cash flow hedges, and we designated them as such. We recorded mark-to-market adjustments as a component of AOCI, and the amount in AOCI is recognized in “Interest expense, net” as the forecasted interest payments occur or if the interest payments are probable not to occur. In June 2020, in connection with the reoffering and conversion of the GoZone Bonds, we terminated forward-starting interest rate swaps with an aggregate notional amount of $250.0 million and paid $49.2 million, which will be amortized into “Interest expense, net” as the related forecasted interest payments occur. The termination payments are included in cash flows from financing activities on the consolidated statements of cash flows. Please see Note 2 for additional information. In conjunction with the early repayment of our $250.0 million 4.75 % senior notes due February 1, 2022 in the fourth quarter of 2021, we reclassified a loss of $0.8 million from AOCI to “Interest expense, net.”
The remaining fair value amounts associated with unwound interest rate swap agreements are presented in the table below. These amounts are amortized ratably over the remaining life of the related debt instrument into “Interest expense, net” on the consolidated statements of income (loss).
| December 31, | ||||||||||||||||||||
| Unwound Interest Rate Swap Agreements | Balance Sheet Location | 2021 | 2020 | |||||||||||||||||
| (Thousands of Dollars) | ||||||||||||||||||||
| Fixed-to-floating | Long-term debt, less current portion | $ | $ | |||||||||||||||||
| Forward-starting | Accumulated other comprehensive loss | $ | ( | $ | ( | |||||||||||||||
Our forward-starting interest rate swaps had the following impact on earnings:
| Year Ended December 31, | ||||||||||||||||||||
| 2021 | 2020 | 2019 | ||||||||||||||||||
| (Thousands of Dollars) | ||||||||||||||||||||
| Change in unrealized loss on cash flow hedges | $ | $ | ( | $ | ( | |||||||||||||||
| Reclassification of loss on cash flow hedges to interest expense, net | $ | $ | $ | |||||||||||||||||
As of December 31, 2021, we expect to reclassify a loss of $2.1 million to “Interest expense, net” within the next twelve months associated with unwound forward-starting interest rate swap agreements.
Fair Value Measurements
We segregate the inputs used in measuring fair value into three levels: Level 1, defined as observable inputs such as quoted prices for identical assets or liabilities in active markets; Level 2, defined as inputs other than quoted prices in active markets that are either directly or indirectly observable, such as quoted prices for similar assets or liabilities in active markets or quoted prices for identical assets or liabilities in markets that are not active; and Level 3, defined as unobservable inputs for which little
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
or no market data exists. We consider counterparty credit risk and our own credit risk in the determination of all estimated fair values.
We recognize cash equivalents, receivables, payables and debt in our consolidated balance sheets at their carrying amounts. The fair values of these financial instruments, except for long-term debt other than finance leases, approximate their carrying amounts. The estimated fair values and carrying amounts of the long-term debt, excluding finance leases, were as follows:
| December 31, | |||||||||||
| 2021 | 2020 | ||||||||||
| (Thousands of Dollars) | |||||||||||
| Fair value | $ | $ | |||||||||
| Carrying amount | $ | $ | |||||||||
We have estimated the fair value of our publicly traded notes based upon quoted prices in active markets; therefore, we determined that the fair value of our publicly traded notes falls in Level 1 of the fair value hierarchy. With regard to our other debt, for which a quoted market price is not available, we have estimated the fair value using a discounted cash flow analysis using current incremental borrowing rates for similar types of borrowing arrangements and determined that the fair value falls in Level 2 of the fair value hierarchy. The carrying value includes net fair value adjustments, unamortized discounts and unamortized debt issuance costs.
17. SERIES D CUMULATIVE CONVERTIBLE PREFERRED UNITS
Series D Preferred Units Issued and Outstanding
On June 26, 2018, the Partnership entered into a purchase agreement (the Series D Preferred Unit Purchase Agreement) with investment funds, accounts and entities (collectively, the Purchasers) managed by EIG Management Company, LLC and FS/EIG Advisors, LLC to issue and sell Series D Cumulative Convertible Preferred Units (Series D Preferred Units) in a private placement. The following is a summary of our Series D Preferred Units issued and outstanding as of December 31, 2021:
| Original Issuance Date | Number of Units Issued and Outstanding | Purchase Price per Unit | ||||||||||||||||||
| Initial Closing | June 29, 2018 | $ | ||||||||||||||||||
| Second Closing | July 13, 2018 | $ | ||||||||||||||||||
| Total | ||||||||||||||||||||
The Series D Preferred Units rank equal to other classes of preferred units and senior to common units in the Partnership with respect to distribution rights and rights upon liquidation. The Series D Preferred Units generally vote on an as-converted basis with the common units and have certain class voting rights with respect to a limited number of matters as set forth in the partnership agreement. The Partnership is required to use its commercially reasonable efforts to register the Series D Preferred Units after the second anniversary of the Initial Closing, no later than one year after receipt of a written request from holders holding a majority of the Series D Preferred Units to register the Series D Preferred Units. If the Partnership fails to cause such registration statement to become effective by the applicable date, the Partnership will be required to pay certain amounts to the holders as liquidated damages.
Series D Preferred Units Distributions
Distributions on the Series D Preferred Units are payable out of any legally available funds, accrue and are cumulative from the issuance dates and are payable on the 15th day (or next business day) of each of March, June, September and December, beginning September 17, 2018, to holders of record on the first business day of each payment month. The distribution rates on the Series D Preferred Units are as follows: (i) 9.75 %, or $57.6 million, per annum ($0.619 per unit per distribution period) for the first two years; (ii) 10.75 %, or $63.4 million, per annum ($0.682 per unit per distribution period) for years three through five; and (iii) the greater of 13.75%, or $81.1 million, per annum ($0.872 per unit per distribution period) or the distribution per common unit thereafter . While the Series D Preferred Units are outstanding, the Partnership will be prohibited from paying distributions on any junior securities, including the common units, unless full cumulative distributions on the Series D Preferred Units (and any parity securities) have been, or contemporaneously are being, paid or set aside for payment through the most recent Series D Preferred Unit distribution payment date. Any Series D Preferred Unit distributions in excess of $0.635 per unit may be paid, in the Partnership’s sole discretion, in additional Series D Preferred Units, with the remainder paid in cash.
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
If we fail to pay in full any Series D Preferred Unit distribution amount, then, until we pay such distributions in full, the applicable distribution rate for each of those distribution periods shall be increased by $0.048 per Series D Preferred Unit. In addition, if we fail to pay in full any Series D Preferred Unit distribution amount for three consecutive distribution periods, then until we pay such distributions in full: (i) each holder of the Series D Preferred Units may elect to convert its Series D Preferred Units into common units on a one-for-one basis, plus any unpaid Series D distributions , (ii) one person selected by the holders holding a majority of the outstanding Series D Preferred Units shall become an additional member of our board of directors and (iii) we will not be permitted to incur any indebtedness (as defined in the Revolving Credit Agreement) or engage in any acquisitions or asset sales in excess of $50.0 million without the consent of the holders holding a majority of the outstanding Series D Preferred Units. In addition, we will permanently lose the ability to pay any part of the distributions on the Series D Preferred Units in the form of additional Series D Preferred Units.
In January 2022, our board of directors declared a distribution of $0.682 per Series D Preferred Unit to be paid on March 15, 2022.
Series D Preferred Units Conversion and Redemption Features
On or after June 29, 2020, each holder of Series D Preferred Units may convert all or any portion of its Series D Preferred Units into common units on a one-for-one basis (plus any unpaid Series D distributions), subject to anti-dilution adjustments, at any time, but not more than once per quarter, so long as any conversion is for at least $50.0 million based on the Purchase Price per Unit (or such lesser amount representing all of a holder’s Series D Preferred Units).
The Partnership may redeem all or any portion of the Series D Preferred Units, in an amount not less than $50.0 million for cash at a redemption price equal to, as applicable: (i) $31.73 per Series D Preferred Unit at any time on or after June 29, 2023 but prior to June 29, 2024; (ii) $30.46 per Series D Preferred Unit at any time on or after June 29, 2024 but prior to June 29, 2025; (iii) $29.19 per Series D Preferred Unit at any time on or after June 29, 2025; plus, in each case, the sum of any unpaid distributions on the applicable Series D Preferred Unit plus the distributions prorated for the number of days elapsed (not to exceed 90 ) in the period of redemption (Series D Partial Period Distributions). The holders have the option to convert the units prior to such redemption as discussed above.
Additionally, at any time on or after June 29, 2028, each holder of Series D Preferred Units will have the right to require the Partnership to redeem all of the Series D Preferred Units held by such holder at a redemption price equal to $29.19 per Series D Preferred Unit plus any unpaid Series D distributions plus the Series D Partial Period Distributions . If a holder of Series D Preferred Units exercises its redemption right, the Partnership may elect to pay up to 50 % of such amount in common units (which shall be valued at 93 % of a volume-weighted average trading price of the common units); provided, that the common units to be issued do not, in the aggregate, exceed 15 % of NuStar Energy’s common equity market capitalization at the time.
Series D Preferred Units Change of Control
Upon certain events involving a change of control, each holder of the Series D Preferred Units may elect to: (i) convert its Series D Preferred Units into common units on a one-for-one basis, plus any unpaid Series D distributions ; (ii) require the Partnership to redeem its Series D Preferred Units for an amount equal to the sum of (a) $29.82 per Series D Preferred Unit plus (b) any unpaid Series D distributions plus (c) the applicable distribution amount for the distribution periods ending after the change of control event and prior to (but including) the fourth anniversary of the Initial Closing ; (iii) if the Partnership is the surviving entity and its common units continue to be listed, continue to hold its Series D Preferred Units; or (iv) if the Partnership will not be the surviving entity, or it will be the surviving entity but its common units will cease to be listed, require the Partnership to use its commercially reasonable efforts to deliver a security in the surviving entity that has substantially similar terms as the Series D Preferred Units; however, if the Partnership is unable to deliver a mirror security, each holder is still entitled to option (i) or (ii) above.
Series D Preferred Units Accounting Treatment
The Series D Preferred Units include redemption provisions at the option of the holders of the Series D Preferred Units and upon a Series D Change of Control (as defined in the partnership agreement), which are outside the Partnership’s control. Therefore, the Series D Preferred Units are presented in the mezzanine section of the consolidated balance sheets. The Series D Preferred Units have been recorded at their issuance date fair value, net of issuance costs. We reassess the presentation of the Series D Preferred Units in our consolidated balance sheets on a quarterly basis.
The Series D Preferred Units are subject to accretion from their carrying value at the issuance date to the redemption value, which is based on the redemption right of the Series D Preferred Unit holders that may be exercised at any time on or after June 29, 2028, using the effective interest method over a period of ten years . In the calculation of net income per unit, the
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NUSTAR ENERGY L.P. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
18. PARTNERS’ EQUITY
Series A, B and C Preferred Units
The following is a summary of our Series A, Series B and Series C Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Units (collectively the Series A, B and C Preferred Units) issued and outstanding as of December 31, 2021:
| Units | Original Issuance Date | Number of Units Issued and Outstanding | Price per Unit | Fixed Distribution Rate per Annum (as a Percentage of the $ | Fixed Distribution Rate per Unit per Annum | Fixed Distribution per Annum (in thousands of dollars) | Optional Redemption Date/Date at Which Distribution Rate Becomes Floating | Floating Annual Rate (as a Percentage of the $ | ||||||||||||||||||||||||||||||||||||||||||
Series A Preferred Units | November 25, 2016 | $ | % | $ | $ | December 15, 2021 | ||||||||||||||||||||||||||||||||||||||||||||
Series B Preferred Units | April 28, 2017 | $ | % | $ | $ | June 15, 2022 | ||||||||||||||||||||||||||||||||||||||||||||
Series C Preferred Units | November 30, 2017 | $ | % | $ | $ | December 15, 2022 | ||||||||||||||||||||||||||||||||||||||||||||
The Series A Preferred Units switched from a fixed distribution rate to a floating rate on December 15, 2021, with the floating rate set forth below for the period indicated:
| Period | Distribution Rate per Unit | Total Distribution | ||||||||||||
| (Thousands of Dollars) | ||||||||||||||
| December 15, 2021 - March 14, 2022 | $ | $ | ||||||||||||
Distributions on the Series A, B and C Preferred Units are payable out of any legally available funds, accrue and are cumulative from the original issuance dates, and are payable on the 15th day (or the next business day) of each of March, June, September and December of each year to holders of record on the first business day of each payment month. The Series A, B and C Preferred Units rank equal to each other and to the Series D Preferred Units, and senior to all of our other classes of equity securities with respect to distribution rights and rights upon liquidation.
In January 2022, our board of directors declared quarterly distributions with respect to the Series A, B and C Preferred Units to be paid on March 15, 2022.
Common Units
Issuances of Common Units. In the fourth quarter of 2019, we issued 527,426 common units at a price of $28.44 per unit to William E. Greehey, Chairman of the Board of Directors of NuStar GP, LLC. We used the proceeds of $15.0 million from the sale of these units for general partnership purposes.
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NUSTAR ENERGY L.P. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
The following table shows the balance of and changes in the number of our common units outstanding:
| Year Ended December 31, | |||||||||||||||||
| 2021 | 2020 | 2019 | |||||||||||||||
| Balance as of the beginning of year | |||||||||||||||||
| Issuance of units | |||||||||||||||||
Unit-based compensation (refer to Note 22 for discussion) | |||||||||||||||||
| Balance as of the end of year | |||||||||||||||||
Cash Distributions. We make quarterly distributions to common unitholders of 100 % of our “Available Cash,” generally defined as cash receipts less cash disbursements, including distributions to our preferred units, and cash reserves established by the general partner, in its sole discretion. These quarterly distributions are declared and paid within 45 days subsequent to each quarter-end. The common unitholders receive a distribution each quarter as determined by the board of directors, subject to limitation by the distributions in arrears, if any, on our preferred units.
The following table summarizes information about cash distributions to our common limited partners applicable to the period in which the distributions were earned:
| Cash Distributions Per Unit | Total Cash Distributions | Record Date | Payment Date | |||||||||||||||||||||||
| (Thousands of Dollars) | ||||||||||||||||||||||||||
| Quarter ended: | ||||||||||||||||||||||||||
| December 31, 2021 | $ | $ | ||||||||||||||||||||||||
| September 30, 2021 | ||||||||||||||||||||||||||
| June 30, 2021 | ||||||||||||||||||||||||||
| March 31, 2021 | ||||||||||||||||||||||||||
Year ended December 31, 2021 | $ | $ | ||||||||||||||||||||||||
Year ended December 31, 2020 | $ | $ | ||||||||||||||||||||||||
Year ended December 31, 2019 | $ | $ | ||||||||||||||||||||||||
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NUSTAR ENERGY L.P. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
Accumulated Other Comprehensive Income (Loss)
The balance of and changes in the components included in AOCI were as follows:
| Foreign Currency Translation | Cash Flow Hedges | Pension and Other Postretirement Benefits | Total | ||||||||||||||||||||
| (Thousands of Dollars) | |||||||||||||||||||||||
| Balance as of January 1, 2019 | $ | ( | $ | ( | $ | ( | $ | ( | |||||||||||||||
| Other comprehensive income (loss) before reclassification adjustments | ( | ( | |||||||||||||||||||||
| Net gain on pension costs reclassified into other income, net | ( | ( | |||||||||||||||||||||
| Net loss on cash flow hedges reclassified into interest expense, net | |||||||||||||||||||||||
| Other comprehensive income (loss) | ( | ( | ( | ||||||||||||||||||||
| Balance as of December 31, 2019 | ( | ( | ( | ( | |||||||||||||||||||
| Other comprehensive income (loss) before reclassification adjustments | ( | ( | ( | ||||||||||||||||||||
| Net gain on pension costs reclassified into other income, net | ( | ( | |||||||||||||||||||||
| Net loss on cash flow hedges reclassified into interest expense, net | |||||||||||||||||||||||
| Other comprehensive income (loss) | ( | ( | ( | ||||||||||||||||||||
| Balance as of December 31, 2020 | ( | ( | ( | ( | |||||||||||||||||||
| Other comprehensive income before reclassification adjustments | |||||||||||||||||||||||
| Net gain on pension costs reclassified into other income, net | ( | ( | |||||||||||||||||||||
| Net loss on cash flow hedges reclassified into interest expense, net | |||||||||||||||||||||||
| Other comprehensive income | |||||||||||||||||||||||
| Balance as of December 31, 2021 | $ | ( | $ | ( | $ | $ | ( | ||||||||||||||||
19. NET INCOME (LOSS) PER COMMON UNIT
As discussed in Note 17, the Series D Preferred Units are convertible into common units at the option of the holder at any time on or after June 29, 2020. As such, we calculated the dilutive effect of the Series D Preferred Units using the if-converted method. The effect of the assumed conversion of the Series D Preferred Units outstanding was antidilutive for each of the years ended December 31, 2021, 2020 and 2019; therefore, we did not include such conversion in the computation of diluted net (loss) income per common unit.
Contingently issuable performance units are included as dilutive potential common units if it is probable that the performance measures will be achieved, unless to do so would be antidilutive. For the years ended December 31, 2021 and 2020, we determined that it was probable that the performance measures would be achieved, but the effect would be antidilutive; therefore, we did not include any contingently issuable performance units as dilutive common units in the computation below.
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NUSTAR ENERGY L.P. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
The following table details the calculation of net income (loss) per common unit:
| Year Ended December 31, | |||||||||||||||||
| 2021 | 2020 | 2019 | |||||||||||||||
| (Thousands of Dollars, Except Unit and Per Unit Data) | |||||||||||||||||
| Net income (loss) | $ | $ | ( | $ | ( | ||||||||||||
| Distributions to preferred limited partners | ( | ( | ( | ||||||||||||||
| Distributions to common limited partners | ( | ( | ( | ||||||||||||||
| Distribution equivalent rights to restricted units | ( | ( | ( | ||||||||||||||
| Distributions in excess of income (loss) | $ | ( | $ | ( | $ | ( | |||||||||||
| Distributions to common limited partners | $ | $ | $ | ||||||||||||||
| Allocation of distributions in excess of income (loss) | ( | ( | ( | ||||||||||||||
Series D Preferred Unit accretion (refer to Note 17) | ( | ( | ( | ||||||||||||||
| Net loss attributable to common units | $ | ( | $ | ( | $ | ( | |||||||||||
| Basic weighted-average common units outstanding | |||||||||||||||||
| Diluted common units outstanding: | |||||||||||||||||
| Basic weighted-average common units outstanding | |||||||||||||||||
| Effect of dilutive potential common units | |||||||||||||||||
| Diluted weighted-average common units outstanding | |||||||||||||||||
| Basic and diluted net loss per common unit | $ | ( | $ | ( | $ | ( | |||||||||||
20. SUPPLEMENTAL CASH FLOW INFORMATION
Changes in current assets and current liabilities were as follows:
| Year Ended December 31, | |||||||||||||||||
| 2021 | 2020 | 2019 | |||||||||||||||
| (Thousands of Dollars) | |||||||||||||||||
| Decrease (increase) in current assets: | |||||||||||||||||
| Accounts receivable | $ | ( | $ | $ | ( | ||||||||||||
| Inventories | ( | ( | |||||||||||||||
| Prepaid and other current assets | ( | ( | ( | ||||||||||||||
| Increase (decrease) in current liabilities: | |||||||||||||||||
| Accounts payable | ( | ||||||||||||||||
| Accrued interest payable | ( | ||||||||||||||||
| Accrued liabilities | ( | ||||||||||||||||
| Taxes other than income tax | ( | ( | |||||||||||||||
| Changes in current assets and current liabilities | $ | ( | $ | $ | ( | ||||||||||||
The above changes in current assets and current liabilities differ from changes between amounts reflected in the applicable consolidated balance sheets due to:
•the change in the amount accrued for capital expenditures;
•the effect of foreign currency translation;
•payments for the termination of interest rate swaps included in cash flows from financing activities;
•the effect of accrued compensation expense paid with fully vested common unit awards;
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NUSTAR ENERGY L.P. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
•the reclassification of certain assets and liabilities to “Assets held for sale” and “Liabilities held for sale” on the consolidated balance sheets (please refer to Note 4 for additional discussion); and
•current assets and current liabilities disposed of during the period.
Cash flows related to interest and income taxes were as follows:
| Year Ended December 31, | |||||||||||||||||
| 2021 | 2020 | 2019 | |||||||||||||||
| (Thousands of Dollars) | |||||||||||||||||
| Cash paid for interest, net of amount capitalized | $ | $ | $ | ||||||||||||||
| Cash paid for income taxes, net of tax refunds received | $ | $ | $ | ||||||||||||||
Restricted cash is included in "Other long-term assets, net" on the consolidated balance sheets. “Cash, cash equivalents and restricted cash” on the consolidated statements of cash flows was included in the consolidated balance sheets as follows:
| December 31, | |||||||||||
| 2021 | 2020 | ||||||||||
| (Thousands of Dollars) | |||||||||||
| Cash and cash equivalents | $ | $ | |||||||||
| Other long-term assets, net | |||||||||||
| Cash, cash equivalents and restricted cash | $ | $ | |||||||||
21. EMPLOYEE BENEFIT PLANS
Thrift Plans
The NuStar Excess Thrift Plan (the Excess Thrift Plan) is a nonqualified deferred compensation plan that became effective July 1, 2006. The Excess Thrift Plan provides benefits to those employees whose compensation and/or annual contributions under the Thrift Plan are subject to the limitations applicable to qualified retirement plans under the Code.
We also maintain other defined contribution plans for certain international employees located in Canada. We maintained plans for international employees in the Caribbean Netherlands prior to the St. Eustatius Disposition on July 29, 2019. For the years ended December 31, 2021, 2020 and 2019, our costs for these plans totaled $0.6 million, $0.5 million and $0.9 million, respectively.
Pension and Other Postretirement Benefits
We also maintain an excess pension plan (the Excess Pension Plan), which is a nonqualified deferred compensation plan that provides benefits to a select group of management or other highly compensated employees. Neither the Excess Thrift Plan nor the Excess Pension Plan is intended to constitute either a qualified plan under the provisions of Section 401 of the Code or a funded plan subject to the Employee Retirement Income Security Act.
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
The Pension Plan and Excess Pension Plan are collectively referred to as the Pension Plans in the tables and discussion below. Our other postretirement benefit plans include a contributory medical benefits plan for U.S. employees who retired prior to April 1, 2014 and, for employees who retire on or after April 1, 2014, a partial reimbursement for eligible third-party health care premiums. We use December 31 as the measurement date for our pension and other postretirement plans.
The changes in the benefit obligation, the changes in fair value of plan assets, the funded status and the amounts recognized in the consolidated balance sheets for our Pension Plans and other postretirement benefit plans as of and for the years ended December 31, 2021 and 2020 were as follows:
| Pension Plans | Other Postretirement Benefit Plans | ||||||||||||||||||||||
| 2021 | 2020 | 2021 | 2020 | ||||||||||||||||||||
| (Thousands of Dollars) | |||||||||||||||||||||||
| Change in benefit obligation: | |||||||||||||||||||||||
| Benefit obligation, January 1 | $ | $ | $ | $ | |||||||||||||||||||
| Service cost | |||||||||||||||||||||||
| Interest cost | |||||||||||||||||||||||
| Benefits paid (a) | ( | ( | ( | ( | |||||||||||||||||||
| Participant contributions | |||||||||||||||||||||||
| Actuarial (gain) loss | ( | ||||||||||||||||||||||
| Other | ( | ||||||||||||||||||||||
| Benefit obligation, December 31 | $ | $ | $ | $ | |||||||||||||||||||
| Change in plan assets: | |||||||||||||||||||||||
| Plan assets at fair value, January 1 | $ | $ | $ | $ | |||||||||||||||||||
| Actual return on plan assets | |||||||||||||||||||||||
| Employer contributions | |||||||||||||||||||||||
| Benefits paid (a) | ( | ( | ( | ( | |||||||||||||||||||
| Participant contributions | |||||||||||||||||||||||
| Plan assets at fair value, December 31 | $ | $ | $ | $ | |||||||||||||||||||
| Reconciliation of funded status: | |||||||||||||||||||||||
| Fair value of plan assets at December 31 | $ | $ | $ | $ | |||||||||||||||||||
| Less: Benefit obligation at December 31 | |||||||||||||||||||||||
| Funded status at December 31 | $ | $ | ( | $ | ( | $ | ( | ||||||||||||||||
| Amounts recognized in the consolidated balance sheets (b): | |||||||||||||||||||||||
| Other long-term assets, net | $ | $ | $ | $ | |||||||||||||||||||
| Accrued liabilities | ( | ( | ( | ( | |||||||||||||||||||
| Other long-term liabilities | ( | ( | ( | ( | |||||||||||||||||||
| Net pension asset (liability) | $ | $ | ( | $ | ( | $ | ( | ||||||||||||||||
| Accumulated benefit obligation | $ | $ | $ | $ | |||||||||||||||||||
(a)Benefit payments for the year ended December 31, 2021 include lump-sum payments of $9.6 million to participants of the Pension Plans following the Eastern U.S. Terminals Disposition on October 8, 2021 and the Texas City Sale on December 7, 2020.
(b)For the Pension Plan, since assets exceed the present value of expected benefit payments for the next 12 months, all of the liability is noncurrent. For the Excess Pension Plan and the other postretirement benefit plans, since there are no
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NUSTAR ENERGY L.P. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
The actuarial (gain) loss related to the benefit obligation for our pension plans was primarily attributable to an increase in the discount rates used to determine the benefit obligation from 2.84 % to 3.10 % in 2021 and a decrease from 3.34 % to 2.84 % in 2020. The fair value of our plan assets is affected by the return on plan assets resulting primarily from the performance of equity and bond markets during the period.
The Excess Pension Plan has no 4.3 million and $3.8 million as of December 31, 2021 and 2020, respectively. The accumulated benefit obligation is the present value of benefits earned to date, while the projected benefit obligation may include future salary increase assumptions. The projected benefit obligation for the Excess Pension Plan was $5.0 million and $3.8 million as of December 31, 2021 and 2020, respectively.
The components of net periodic benefit cost (income) related to our Pension Plans and other postretirement benefit plans were as follows:
| Pension Plans | Other Postretirement Benefit Plans | ||||||||||||||||||||||||||||||||||
| Year Ended December 31, | Year Ended December 31, | ||||||||||||||||||||||||||||||||||
| 2021 | 2020 | 2019 | 2021 | 2020 | 2019 | ||||||||||||||||||||||||||||||
| (Thousands of Dollars) | |||||||||||||||||||||||||||||||||||
| Service cost | $ | $ | $ | $ | $ | $ | |||||||||||||||||||||||||||||
| Interest cost | |||||||||||||||||||||||||||||||||||
| Expected return on plan assets | ( | ( | ( | ||||||||||||||||||||||||||||||||
| Amortization of prior service credit | ( | ( | ( | ( | ( | ( | |||||||||||||||||||||||||||||
| Amortization of net actuarial loss | |||||||||||||||||||||||||||||||||||
| Other | ( | ||||||||||||||||||||||||||||||||||
| Net periodic benefit cost (income) | $ | $ | $ | $ | ( | $ | ( | $ | ( | ||||||||||||||||||||||||||
The service cost component of net periodic benefit cost (income) is reported in “General and administrative expenses” and “Operating expenses” on the consolidated statements of income (loss), and the remaining components of net periodic benefit cost (income) are reported in “Other income (expense), net.”
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
Adjustments to other comprehensive income (loss) related to our Pension Plans and other postretirement benefit plans were as follows:
| Pension Plans | Other Postretirement Benefit Plans | ||||||||||||||||||||||||||||||||||
| Year Ended December 31, | Year Ended December 31, | ||||||||||||||||||||||||||||||||||
| 2021 | 2020 | 2019 | 2021 | 2020 | 2019 | ||||||||||||||||||||||||||||||
| (Thousands of Dollars) | |||||||||||||||||||||||||||||||||||
| Net unrecognized gain (loss) arising during the year: | |||||||||||||||||||||||||||||||||||
| Net actuarial gain (loss) | $ | $ | ( | $ | $ | ( | $ | ( | $ | ( | |||||||||||||||||||||||||
| Net (gain) loss reclassified into income: | |||||||||||||||||||||||||||||||||||
| Amortization of prior service credit | ( | ( | ( | ( | ( | ( | |||||||||||||||||||||||||||||
| Amortization of net actuarial loss | |||||||||||||||||||||||||||||||||||
| Other | ( | ||||||||||||||||||||||||||||||||||
| Net gain reclassified into income | ( | ( | ( | ( | ( | ( | |||||||||||||||||||||||||||||
| Income tax (expense) benefit | ( | ||||||||||||||||||||||||||||||||||
| Total changes to other comprehensive income (loss) | $ | $ | ( | $ | $ | ( | $ | ( | $ | ( | |||||||||||||||||||||||||
The amounts recorded as a component of “Accumulated other comprehensive loss” on the consolidated balance sheets related to our Pension Plans and other postretirement benefit plans were as follows:
| Pension Plans | Other Postretirement Benefit Plans | ||||||||||||||||||||||
| December 31, | December 31, | ||||||||||||||||||||||
| 2021 | 2020 | 2021 | 2020 | ||||||||||||||||||||
| (Thousands of Dollars) | |||||||||||||||||||||||
| Unrecognized actuarial loss | $ | ( | $ | ( | $ | ( | $ | ( | |||||||||||||||
| Prior service credit | |||||||||||||||||||||||
| Deferred tax asset | |||||||||||||||||||||||
Accumulated other comprehensive income (loss), net of tax | $ | $ | ( | $ | $ | ||||||||||||||||||
Investment Policies and Strategies
The investment policies and strategies for the assets of our qualified Pension Plan incorporate a well-diversified approach that is expected to earn long-term returns from capital appreciation and a growing stream of current income. This approach recognizes that assets are exposed to risk, and the market value of the Pension Plan’s assets may fluctuate from year to year. Risk tolerance is determined based on our financial ability to withstand risk within the investment program and the willingness to accept return volatility. In line with the investment return objective and risk parameters, the Pension Plan’s mix of assets includes a diversified portfolio of equity and fixed-income instruments. The aggregate asset allocation is reviewed on an annual basis. As of December 31, 2021, the target allocations for plan assets were 65 % equity securities and 35 % fixed income investments, with certain fluctuations permitted.
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Fair Value of Plan Assets
We disclose the fair value for each major class of plan assets in the Pension Plan in three levels: Level 1, defined as observable inputs such as quoted prices for identical assets or liabilities in active markets; Level 2, defined as inputs other than quoted prices in active markets that are either directly or indirectly observable, such as quoted prices for similar assets or liabilities in active markets or quoted prices for identical assets or liabilities in markets that are not active; and Level 3, defined as unobservable inputs for which little or no market data exists.
The major classes of plan assets measured at fair value for the Pension Plan were as follows:
| December 31, 2021 | |||||||||||||||||||||||
| Level 1 | Level 2 | Level 3 | Total | ||||||||||||||||||||
| (Thousands of Dollars) | |||||||||||||||||||||||
| Cash equivalent securities | $ | $ | $ | $ | |||||||||||||||||||
| Equity securities: | |||||||||||||||||||||||
| U.S. large cap equity fund (a) | |||||||||||||||||||||||
| International stock index fund (b) | |||||||||||||||||||||||
| Fixed income securities: | |||||||||||||||||||||||
| Bond market index fund (c) | |||||||||||||||||||||||
| Total | $ | $ | $ | $ | |||||||||||||||||||
| December 31, 2020 | |||||||||||||||||||||||
| Level 1 | Level 2 | Level 3 | Total | ||||||||||||||||||||
| (Thousands of Dollars) | |||||||||||||||||||||||
| Cash equivalent securities | $ | $ | $ | $ | |||||||||||||||||||
| Equity securities: | |||||||||||||||||||||||
| U.S. large cap equity fund (a) | |||||||||||||||||||||||
| International stock index fund (b) | |||||||||||||||||||||||
| Fixed income securities: | |||||||||||||||||||||||
| Bond market index fund (c) | |||||||||||||||||||||||
| Total | $ | $ | $ | $ | |||||||||||||||||||
(a)This fund is a low-cost equity index fund not actively managed that tracks the S&P 500. Fair values were estimated using pricing models, quoted prices of securities with similar characteristics or discounted cash flows.
(b)This fund tracks the performance of the Total International Composite Index.
(c)This fund tracks the performance of the Barclays Capital U.S. Aggregate Bond Index.
Contributions to the Pension Plans
For the year ended December 31, 2021, we contributed $0.1 million and $0.2 million to the Pension Plans and other postretirement benefit plans, respectively. During 2022, we expect to contribute approximately $9.5 million and $0.4 million to the Pension Plans and other postretirement benefit plans, respectively. We will monitor our funding status in 2022 to determine if any contributions are required by regulations or laws, or with respect to unfunded plans, necessary to fund current benefits.
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
Estimated Future Benefit Payments
The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid for the years ending December 31:
| Pension Plans | Other Postretirement Benefit Plans | ||||||||||
| (Thousands of Dollars) | |||||||||||
| 2022 | $ | $ | |||||||||
| 2023 | $ | $ | |||||||||
| 2024 | $ | $ | |||||||||
| 2025 | $ | $ | |||||||||
| 2026 | $ | $ | |||||||||
| 2027-2031 | $ | $ | |||||||||
Assumptions
The weighted-average assumptions used to determine the benefit obligations were as follows:
| Pension Plans | Other Postretirement Benefit Plans | ||||||||||||||||||||||
| December 31, | December 31, | ||||||||||||||||||||||
| 2021 | 2020 | 2021 | 2020 | ||||||||||||||||||||
| Discount rate | % | % | % | % | |||||||||||||||||||
| Rate of compensation increase | % | % | n/a | n/a | |||||||||||||||||||
| Cash balance interest crediting rate | % | % | n/a | n/a | |||||||||||||||||||
The weighted-average assumptions used to determine the net periodic benefit cost (income) were as follows:
| Pension Plans | Other Postretirement Benefit Plans | ||||||||||||||||||||||||||||||||||
| Year Ended December 31, | Year Ended December 31, | ||||||||||||||||||||||||||||||||||
| 2021 | 2020 | 2019 | 2021 | 2020 | 2019 | ||||||||||||||||||||||||||||||
| Discount rate | % | % | % | % | % | % | |||||||||||||||||||||||||||||
Expected long-term rate of return on plan assets | % | % | % | n/a | n/a | n/a | |||||||||||||||||||||||||||||
| Rate of compensation increase | % | % | % | n/a | n/a | n/a | |||||||||||||||||||||||||||||
| Cash balance interest crediting rate | % | % | % | n/a | n/a | n/a | |||||||||||||||||||||||||||||
The assumed health care cost trend rates were as follows:
| December 31, | |||||||||||
| 2021 | 2020 | ||||||||||
| Health care cost trend rate assumed for next year | % | % | |||||||||
| Rate to which the cost trend rate was assumed to decrease (the ultimate trend rate) | % | % | |||||||||
| Year that the rate reaches the ultimate trend rate | |||||||||||
We sponsor a contributory postretirement health care plan for employees who retired prior to April 1, 2014. The plan has an annual limitation (a cap) on the increase of the employer’s share of the cost of covered benefits. The cap on the increase in employer’s cost is 2.5% per year.
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NUSTAR ENERGY L.P. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
22. UNIT-BASED COMPENSATION
Overview
2019 LTIP. In April 2019, our common unitholders approved the 2019 Long-Term Incentive Plan (2019 LTIP) for eligible employees, consultants and directors of NuStar Energy L.P., and of NuStar GP, LLC, and their respective affiliates who perform services for us and our subsidiaries. The 2019 LTIP allows for the awarding of (i) options; (ii) restricted units; (iii) distribution equivalent rights (DERs); (iv) performance cash; (v) performance units; and (vi) unit awards. DERs entitle the participant to receive cash equal to cash distributions made on any award prior to its vesting. The 2019 LTIP, as amended and restated on April 29, 2021, permits the granting of awards totaling an aggregate of 5,000,000 common units, and is subject to adjustment. The 2019 LTIP generally will be administered by the compensation committee of our board of directors. As of December 31, 2021, a total of 2,179,072 common units remained available to be awarded under the 2019 LTIP.
Other Plans. We sponsor the NuStar GP, LLC Fifth Amended and Restated 2000 Long-Term Incentive Plan, as amended (2000 LTIP), and the NuStar GP Holdings, LLC Long-Term Incentive Plan, as amended (2006 LTIP). Effective with the approval of the 2019 LTIP in April 2019, the 2000 LTIP and the 2006 LTIP terminated with respect to new grants; however, unvested restricted unit awards granted under the 2000 LTIP and the 2006 LTIP remain outstanding as of December 31, 2021.
The following table summarizes information pertaining to all of our long-term incentive plans:
| Units Outstanding December 31, | Compensation Expense Year Ended December 31, | ||||||||||||||||||||||||||||||||||
| 2021 | 2020 | 2019 | 2021 | 2020 | 2019 | ||||||||||||||||||||||||||||||
| (Thousands of Dollars) | |||||||||||||||||||||||||||||||||||
| Restricted units: | |||||||||||||||||||||||||||||||||||
| Domestic employees | $ | $ | $ | ||||||||||||||||||||||||||||||||
| Non-employee directors (NEDs) | |||||||||||||||||||||||||||||||||||
| International employees | |||||||||||||||||||||||||||||||||||
| Performance awards | |||||||||||||||||||||||||||||||||||
| Unit awards | |||||||||||||||||||||||||||||||||||
| Total | $ | $ | $ | ||||||||||||||||||||||||||||||||
96
NUSTAR ENERGY L.P. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
Restricted Units
Our restricted unit awards are considered phantom units, as they represent the right to receive our common units upon vesting. We account for restricted units as either equity-classified awards or liability-classified awards, depending on expected method of settlement. Awards we settle with the issuance of common units upon vesting are equity-classified. Awards we settle in cash upon vesting are liability-classified. We record compensation expense ratably over the vesting period based on the fair value of the common units at the grant date (for domestic employees and NEDs) or the fair value of the common units measured at each reporting period (for international employees). DERs paid with respect to outstanding equity-classified unvested restricted units reduce equity, similar to cash distributions to unitholders, whereas DERs paid with respect to outstanding liability-classified unvested restricted units are expensed. In connection with the DERs for equity awards, we paid $2.4 million, $2.1 million and $2.7 million respectively, in cash, for the years ended December 31, 2021, 2020 and 2019.
Domestic Employees. The outstanding restricted units granted to domestic employees are equity-classified awards and generally vest over five years , beginning one year after the grant date. The fair value of these awards is measured at the grant date.
Non-Employee Directors. The outstanding restricted units granted to NEDs are equity-classified awards that vest over three years . On January 1, 2019 we adopted amended guidance that allows for the fair value of these awards to be measured at the grant date. The unvested restricted units granted to NEDs as of January 1, 2019 were measured at the fair value as of that date. Previously, the fair value of these awards was equal to the market price of our common units at each reporting period.
International Employees. The outstanding restricted units granted to international employees are cash-settled and accounted for as liability-classified awards. These awards vest over three years and the fair value is equal to the market price of our common units at each reporting period. For the year ended December 31, 2021, we granted 10,396 restricted units and 8,344 restricted units vested.
A summary of our equity-classified restricted unit awards is as follows:
| Measured at Grant Date Fair Value | |||||||||||
| Number of Units | Weighted-Average Fair Value Per Unit | ||||||||||
Nonvested units as of January 1, 2019 (a) | $ | ||||||||||
| Granted | |||||||||||
| Vested | ( | ||||||||||
| Forfeited | ( | ||||||||||
Nonvested units as of December 31, 2019 | |||||||||||
| Granted | |||||||||||
| Vested | ( | ||||||||||
| Forfeited | ( | ||||||||||
Nonvested units as of December 31, 2020 | |||||||||||
| Granted | |||||||||||
| Vested | ( | ||||||||||
| Forfeited | ( | ||||||||||
Nonvested units as of December 31, 2021 | |||||||||||
(a) Upon adoption of amended guidance, nonvested units include 59,752 units issued to NEDs which were measured at a fair value per unit of $20.93 .
The total fair value of our equity-classified restricted unit awards vested for the years ended December 31, 2021, 2020 and 2019 was $10.3 million, $4.6 million and $9.3 million, respectively. We issued 460,076 , 275,146 and 242,199 common units in connection with these award vestings, net of employee tax withholding requirements, for the years ended December 31, 2021, 2020 and 2019, respectively. Unrecognized compensation cost related to our equity-classified employee awards totaled $42.0 million as of December 31, 2021, which we expect to recognize over a weighted-average period of 3.7 years.
97
NUSTAR ENERGY L.P. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
Performance Awards
A summary of our performance awards is shown below:
| Performance Unit Awards | |||||||||||||||||||||||
| Granted for Accounting Purposes | |||||||||||||||||||||||
| Performance Cash Awards | Total Performance Unit Awards Granted | Performance Unit Awards | Weighted-Average Grant Date Fair Value per Unit | ||||||||||||||||||||
| (Thousands of Dollars) | |||||||||||||||||||||||
Outstanding as of January 1, 2019 | $ | — | $ | ||||||||||||||||||||
| Granted | — | ||||||||||||||||||||||
| Vested | — | ( | ( | ||||||||||||||||||||
| Forfeitures | — | ( | |||||||||||||||||||||
Outstanding as of December 31, 2019 | — | ||||||||||||||||||||||
| Granted | |||||||||||||||||||||||
| Performance adjustment (a) | — | ||||||||||||||||||||||
| Vested | ( | ( | |||||||||||||||||||||
Outstanding as of December 31, 2020 | |||||||||||||||||||||||
| Granted | |||||||||||||||||||||||
| Vested (b) | ( | ( | ( | ||||||||||||||||||||
| Forfeitures | ( | ( | ( | ||||||||||||||||||||
Outstanding as of December 31, 2021 | $ | ||||||||||||||||||||||
(a) For the year ended December 31, 2020, common units granted and issued upon vesting of performance units earned at 198 % of the 2019 target.
(b) For the year ended December 31, 2021, we settled performance cash awards in common units and issued 26,704 common units, net of employee tax withholding requirements.
The total fair value of our performance unit awards vested for the years ended December 31, 2021, 2020 and 2019 was $0.8 million, $4.2 million and $2.1 million, respectively. For the years ended December 31, 2021, 2020, and 2019 we issued 31,366 , 93,440 and 50,054 common units in connection with the performance unit award vestings, net of employee tax withholding requirements, respectively.
On January 27, 2022, we settled performance cash awards in common units, and together with the performance unit awards, we issued 114,618 common units, net of employee tax withholding requirements, respectively.
98
NUSTAR ENERGY L.P. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
Unit Awards
| Date of Grant | Grant Date Fair Value | Unit Awards Granted | Common Units Issued, Net of Employee Withholding Tax | |||||||||||||||||
| (Thousands of Dollars) | ||||||||||||||||||||
| February 2022 | $ | |||||||||||||||||||
| February and March 2020 | $ | |||||||||||||||||||
23. INCOME TAXES
Components of income tax expense related to certain of our continuing operations conducted through separate taxable wholly owned corporate subsidiaries were as follows:
| Year Ended December 31, | |||||||||||||||||
| 2021 | 2020 | 2019 | |||||||||||||||
| (Thousands of Dollars) | |||||||||||||||||
| Current: | |||||||||||||||||
| U.S. | $ | $ | $ | ||||||||||||||
| Foreign | |||||||||||||||||
| Foreign withholding tax | |||||||||||||||||
| Total current | |||||||||||||||||
| Deferred: | |||||||||||||||||
| U.S. | ( | ( | |||||||||||||||
| Foreign | ( | ( | ( | ||||||||||||||
| Foreign withholding tax | ( | ||||||||||||||||
| Total deferred | ( | ( | |||||||||||||||
| Less: amounts reported in discontinued operations | |||||||||||||||||
| Income tax expense | $ | $ | $ | ||||||||||||||
The difference between income tax expense recorded in our consolidated statements of income (loss) and income taxes computed by applying the applicable statutory federal income tax rate to income before income tax expense is due to the fact that the majority of our income is not subject to federal income tax due to our status as a limited partnership. We record a tax provision related to the amount of undistributed earnings of our foreign subsidiaries expected to be repatriated.
99
NUSTAR ENERGY L.P. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
The tax effects of significant temporary differences representing deferred income tax assets and liabilities were as follows:
| December 31, | |||||||||||
| 2021 | 2020 | ||||||||||
| (Thousands of Dollars) | |||||||||||
| Deferred income tax assets: | |||||||||||
| Net operating losses | $ | $ | |||||||||
| Employee benefits | |||||||||||
| Environmental and legal reserves | |||||||||||
| Capital loss | |||||||||||
| Other | |||||||||||
| Total deferred income tax assets | |||||||||||
| Less: Valuation allowance | ( | ( | |||||||||
| Net deferred income tax assets | |||||||||||
| Deferred income tax liabilities: | |||||||||||
| Property, plant and equipment | ( | ( | |||||||||
| Foreign withholding tax | ( | ( | |||||||||
| Other | ( | ( | |||||||||
| Total deferred income tax liabilities | ( | ( | |||||||||
| Net deferred income tax liability | $ | ( | $ | ( | |||||||
As of December 31, 2021, our U.S. and foreign corporate operations have net operating loss carryforwards for tax purposes totaling $63.4 million and $6.9 million, respectively, which are subject to various limitations on use and expire in years 2025 through 2034 for U.S. losses and in years 2021 through 2031 for foreign losses. However, U.S. losses generated after December 31, 2017, totaling $9.4 million, can be carried forward indefinitely. As of December 31, 2021, our U.S. corporate operations have a capital loss carryforward for tax purposes totaling $17.7 million, which is subject to limitations on use and expires in 2024. The capital loss carryforward decreased $33.8 million for the year ended December 31, 2021 due to changes in our estimates of loss carryforwards following the Texas City Sale.
As of December 31, 2021 and 2020, we have a valuation allowance of $23.7 million and $28.2 million, respectively, related to our deferred tax assets on net operating losses and capital losses. We estimate the amount of valuation allowance based upon our expectations of taxable income in the various jurisdictions in which we operate and the period over which we can utilize those future deductions. The valuation allowance reflects uncertainties related to our ability to utilize certain net operating loss carryforwards before they expire. In 2021, there was a $4.9 million decrease in the valuation allowance for the U.S. net operating loss and a $0.4 million increase in the foreign net operating loss valuation allowance due to changes in our estimates of the amount of loss carryforwards that will be realized, based upon future taxable income.
The realization of net deferred income tax assets recorded as of December 31, 2021 is dependent upon our ability to generate future taxable income in the United States. We believe it is more likely than not that the net deferred income tax assets as of December 31, 2021 will be realized, based on expected future taxable income.
100
NUSTAR ENERGY L.P. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
24. SEGMENT INFORMATION
Our reportable business segments consist of the pipeline, storage and fuels marketing segments. Our segments represent strategic business units that offer different services and products. We evaluate the performance of each segment based on its respective operating income, before general and administrative expenses and certain non-segmental depreciation and amortization expense. General and administrative expenses are not allocated to the operating segments since those expenses relate primarily to the overall management at the entity level. We are primarily engaged in the transportation, terminalling and storage of petroleum products and renewable fuels and the transportation of anhydrous ammonia. We also market petroleum products.
Results of operations for the reportable segments were as follows:
| Year Ended December 31, | |||||||||||||||||
| 2021 | 2020 | 2019 | |||||||||||||||
| (Thousands of Dollars) | |||||||||||||||||
| Revenues: | |||||||||||||||||
| Pipeline | $ | $ | $ | ||||||||||||||
| Storage | |||||||||||||||||
| Fuels marketing | |||||||||||||||||
| Consolidation and intersegment eliminations | ( | ( | ( | ||||||||||||||
| Total revenues | $ | $ | $ | ||||||||||||||
| Depreciation and amortization expense: | |||||||||||||||||
| Pipeline | $ | $ | $ | ||||||||||||||
| Storage | |||||||||||||||||
| Total segment depreciation and amortization expense | |||||||||||||||||
| Other depreciation and amortization expense | |||||||||||||||||
| Total depreciation and amortization expense | $ | $ | $ | ||||||||||||||
| Operating income: | |||||||||||||||||
| Pipeline | $ | $ | $ | ||||||||||||||
| Storage | |||||||||||||||||
| Fuels marketing | |||||||||||||||||
| Consolidation and intersegment eliminations | ( | ||||||||||||||||
| Total segment operating income | |||||||||||||||||
| General and administrative expenses | |||||||||||||||||
| Other depreciation and amortization expense | |||||||||||||||||
| Total operating income | $ | $ | $ | ||||||||||||||
Revenues by geographic area are shown in the table below:
| Year Ended December 31, | |||||||||||||||||
| 2021 | 2020 | 2019 | |||||||||||||||
| (Thousands of Dollars) | |||||||||||||||||
| United States | $ | $ | $ | ||||||||||||||
| Foreign | |||||||||||||||||
| Consolidated revenues | $ | $ | $ | ||||||||||||||
101
NUSTAR ENERGY L.P. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
Total amounts of property, plant and equipment, net by geographic area were as follows:
| December 31, | |||||||||||
| 2021 | 2020 | ||||||||||
| (Thousands of Dollars) | |||||||||||
| United States | $ | $ | |||||||||
| Foreign | |||||||||||
| Consolidated property, plant and equipment, net | $ | $ | |||||||||
Total assets by reportable segment were as follows:
| December 31, | |||||||||||
| 2021 | 2020 | ||||||||||
| (Thousands of Dollars) | |||||||||||
| Pipeline | $ | $ | |||||||||
| Storage | |||||||||||
| Fuels marketing | |||||||||||
| Total segment assets | |||||||||||
| Other partnership assets | |||||||||||
| Total consolidated assets | $ | $ | |||||||||
Capital expenditures by reportable segment were as follows:
| Year Ended December 31, | |||||||||||||||||
| 2021 | 2020 | 2019 | |||||||||||||||
| (Thousands of Dollars) | |||||||||||||||||
| Pipeline | $ | $ | $ | ||||||||||||||
| Storage | |||||||||||||||||
| Other partnership assets | |||||||||||||||||
| Total capital expenditures | $ | $ | $ | ||||||||||||||
Capital expenditures have not been adjusted to separately disclose those capital expenditures related to discontinued operations, which are included in the storage segment totaling $28.0 million for the year ended December 31, 2019.
25. SUBSEQUENT EVENT
102
ITEM 9.CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE
None.
ITEM 9A.CONTROLS AND PROCEDURES
DISCLOSURE CONTROLS AND PROCEDURES
Our management has evaluated, with the participation of the principal executive officer and principal financial officer of NuStar GP, LLC, the effectiveness of our disclosure controls and procedures (as defined in Rule 13a-15(e) under the Securities Exchange Act of 1934) as of the end of the period covered by this report, and has concluded that our disclosure controls and procedures were effective as of December 31, 2021.
INTERNAL CONTROL OVER FINANCIAL REPORTING
(a)Management’s Report on Internal Control over Financial Reporting.
Management’s report on NuStar Energy L.P.’s internal control over financial reporting appears in Item 8. of this Form 10-K, and is incorporated herein by reference.
(b)Attestation Report of the Registered Public Accounting Firm.
The report of KPMG LLP on NuStar Energy L.P.’s internal control over financial reporting appears in Item 8. of this Form 10-K, and is incorporated herein by reference.
(c)Changes in Internal Control over Financial Reporting.
There has been no change in our internal control over financial reporting that occurred during our last fiscal quarter that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.
ITEM 9B.OTHER INFORMATION
None.
ITEM 9C.DISCLOSURE REGARDING FOREIGN JURISDICTIONS THAT PREVENT INSPECTIONS
Not applicable.
103
PART III
ITEM 10.DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
Information required to be disclosed under this Item 10 is incorporated by reference to the following sections of our Proxy Statement for the 2022 annual meeting of unitholders, which is expected to be filed within 120 days after the end of the fiscal year covered by this Form 10-K (Proxy Statement): “Corporate Governance-Board Leadership and Governance;” “Corporate Governance-Committees of the Board;” “Corporate Governance-Governance Documents and Codes of Ethics;” “Corporate Governance-Director Candidates;” “Corporate Governance-Communications with the Board of Directors;” “Proposal No. 1 Election of Directors;” and “Information About Our Executive Officers.”
ITEM 11. EXECUTIVE COMPENSATION
Information required to be disclosed under this Item 11 is incorporated by reference to the following sections of our Proxy Statement: “Corporate Governance-Compensation Committee Interlocks and Insider Participation;” “Compensation Committee Report;” “Compensation Discussion and Analysis;” “Evaluation of Compensation Risk;” “Summary Compensation Table;” “Pay Ratio;” “Grants of Plan-Based Awards During the Year Ended December 31, 2021;” “Outstanding Equity Awards at December 31, 2021;” “Option Exercises and Units Vested During the Year Ended December 31, 2021;” “Pension Benefits for the Year Ended December 31, 2021;” “Nonqualified Deferred Compensation for the Year Ended December 31, 2021;” “Potential Payments Upon Termination or Change of Control;” and “Director Compensation.”
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED UNITHOLDER MATTERS
Information required to be disclosed under this Item 12 is incorporated by reference to the following sections of our Proxy Statement: “Security Ownership-Security Ownership of Management and Directors;” “Security Ownership-Security Ownership of Certain Beneficial Owners;” and “Security Ownership-Equity Compensation Plan Information.”
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS AND DIRECTOR INDEPENDENCE
Information required to be disclosed under this Item 13 is incorporated by reference to the following sections of our Proxy Statement: “Corporate Governance-Director Independence;” “Corporate Governance-Board Leadership and Governance;” and “Certain Relationships and Related Party Transactions.”
ITEM 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES
Our independent registered public accounting firm is KPMG LLP , San Antonio, Texas , Auditor Firm ID: 185 .
Information required to be disclosed under this Item 14 is incorporated by reference to the following sections of our Proxy Statement: “KPMG Fees;” and “Audit Committee Pre-Approval Policy.”
104
PART IV
ITEM 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES
| (a) | (1) | Financial Statements. The following consolidated financial statements of NuStar Energy L.P. and its subsidiaries are included in Part II, Item 8 of this Form 10-K: | ||||||||||||
| (2) | Financial Statement Schedules and Other Financial Information. No financial statement schedules are submitted because either they are inapplicable or because the required information is included in the consolidated financial statements or notes thereto. | |||||||||||||
| (3) | Exhibits. | |||||||||||||
The following are filed or furnished, as applicable, as part of this Form 10-K: | ||||||||||||||
| Exhibit Number | Description | Incorporated by Reference to the Following Document | ||||||||||||
| 3.01 | NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2001 (File No. 001-16417), Exhibit 3.3 | |||||||||||||
| 3.02 | NuStar Energy L.P.’s Current Report on Form 8-K filed March 27, 2007 (File No. 001-16417), Exhibit 3.01 | |||||||||||||
| 3.03 | NuStar Energy L.P.’s Current Report on Form 8-K filed July 20, 2018 (File No. 001-16417), Exhibit 3.1 | |||||||||||||
| 3.04 | NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2001 (File No. 001-16417), Exhibit 3.8 | |||||||||||||
| 3.05 | NuStar Energy L.P.’s Quarterly Report on Form 10-Q for quarter ended March 31, 2007 (File No. 001-16417), Exhibit 3.03 | |||||||||||||
| 3.06 | NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2014 (File No. 001-16417), Exhibit 3.09 | |||||||||||||
| 3.07 | NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2001 (File No. 001-16417), Exhibit 3.9 | |||||||||||||
| 3.08 | NuStar Energy L.P.’s Quarterly Report on Form 10-Q for quarter ended June 30, 2001 (File No. 001-16417), Exhibit 4.1 | |||||||||||||
| 3.09 | NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2001 (File No. 001-16417), Exhibit 3.10 | |||||||||||||
105
| Exhibit Number | Description | Incorporated by Reference to the Following Document | ||||||||||||
| 3.10 | NuStar Energy L.P.’s Registration Statement on Form S-1 filed August 14, 2000 (File No. 333-43668), Exhibit 3.7 | |||||||||||||
| 3.11 | NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2001 (File No. 001-16417), Exhibit 3.16 | |||||||||||||
| 3.12 | NuStar Energy L.P.’s Registration Statement on Form S-1 filed August 14, 2000 (File No. 333-43668), Exhibit 3.9 | |||||||||||||
| 3.13 | NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2001 (File No. 001-16417), Exhibit 3.14 | |||||||||||||
| 3.14 | NuStar Energy L.P.’s Quarterly Report on Form 10-Q for quarter ended March 31, 2007 (File No. 001-16417), Exhibit 3.02 | |||||||||||||
| 3.15 | NuStar Energy L.P.’s Current Report on Form 8-K filed July 20, 2018 (File No. 001-16417), Exhibit 3.2 | |||||||||||||
| 4.01 | * | |||||||||||||
| 4.02 | NuStar Energy L.P.’s Current Report on Form 8-K filed July 15, 2002 (File No. 001-16417), Exhibit 4.1 | |||||||||||||
| 4.03 | NuStar Energy L.P.’s Quarterly Report on Form 10-Q for quarter ended June 30, 2005 (File No. 001-16417), Exhibit 4.02 | |||||||||||||
| 4.04 | NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2008 (File No. 001-16417), Exhibit 4.05 | |||||||||||||
| 4.05 | NuStar Energy L.P.’s Current Report on Form 8-K filed April 28, 2017 (File No. 001-16417), Exhibit 4.4 | |||||||||||||
| 4.06 | NuStar Energy L.P.’s Current Report on Form 8-K filed May 22, 2019 (File No. 001-16417), Exhibit 4.3 | |||||||||||||
| 4.07 | NuStar Energy L.P.’s Current Report on Form 8-K filed September 14, 2020 (File No. 001-16417), Exhibit 4.3 | |||||||||||||
106
| Exhibit Number | Description | Incorporated by Reference to the Following Document | ||||||||||||
| 4.08 | NuStar Energy L.P.’s Current Report on Form 8-K filed January 22, 2013 (File No. 001-16417), Exhibit 4.1 | |||||||||||||
| 4.09 | NuStar Energy L.P.’s Current Report on Form 8-K filed January 22, 2013 (File No. 001-16417), Exhibit 4.2 | |||||||||||||
| 4.10 | NuStar Energy L.P.’s Current Report on Form 8-K filed June 29, 2018 (File No. 001-16417), Exhibit 4.2 | |||||||||||||
| 10.01 | NuStar Energy L.P.’s Current Report on Form 8-K filed January 31, 2022 (File No. 001-16417), Exhibit 10.01 | |||||||||||||
| 10.02 | NuStar Energy L.P.’s Current Report on Form 8-K filed June 5, 2020 (File No. 001-16417), Exhibit 10.1 | |||||||||||||
| 10.03 | NuStar Energy L.P.’s Current Report on Form 8-K filed June 5, 2020 (File No. 001-16417), Exhibit 10.2 | |||||||||||||
| 10.04 | NuStar Energy L.P.’s Current Report on Form 8-K filed July 21, 2010 (File No. 001-16417), Exhibit 10.01 | |||||||||||||
| 10.05 | NuStar Energy L.P.’s Current Report on Form 8-K filed June 5, 2020 (File No. 001-16417), Exhibit 10.4 | |||||||||||||
| 10.06 | NuStar Energy L.P.’s Current Report on Form 8-K filed June 5, 2020 (File No. 001-16417), Exhibit 10.5 | |||||||||||||
| 10.07 | NuStar Energy L.P.’s Current Report on Form 8-K filed June 5, 2020 (File No. 001-16417), Exhibit 10.6 | |||||||||||||
| 10.08 | NuStar Energy L.P.’s Current Report on Form 8-K filed December 30, 2010 (File No. 001-16417), Exhibit 10.01 | |||||||||||||
107
| Exhibit Number | Description | Incorporated by Reference to the Following Document | ||||||||||||
| 10.09 | NuStar Energy L.P.’s Current Report on Form 8-K filed June 5, 2020 (File No. 001-16417), Exhibit 10.8 | |||||||||||||
| 10.10 | NuStar Energy L.P.’s Current Report on Form 8-K filed August 10, 2011 (File No. 001-16417), Exhibit 10.01 | |||||||||||||
| 10.11 | NuStar Energy L.P.’s Current Report on Form 8-K filed June 5, 2020 (File No. 001-16417), Exhibit 10.10 | |||||||||||||
| 10.12 | NuStar Energy L.P.'s Current Report on Form 8-K filed June 19, 2015 (File No. 001-16417), Exhibit 10.1 | |||||||||||||
| 10.13 | NuStar Energy L.P.'s Current Report on Form 8-K filed June 19, 2015 (File No. 001-16417), Exhibit 10.2 | |||||||||||||
| 10.14 | NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2015 (File No. 001-16417), Exhibit 10.26 | |||||||||||||
| 10.15 | NuStar Energy L.P.’s Current Report on Form 8-K filed September 20, 2017 (File No. 001-16417), Exhibit 10.01 | |||||||||||||
| 10.16 | NuStar Energy L.P.’s Current Report on Form 8-K filed September 20, 2017 (File No. 001-16417), Exhibit 10.02 | |||||||||||||
| 10.17 | NuStar Energy L.P.’s Current Report on Form 8-K filed March 28, 2018 (File No. 001-16417), Exhibit 10.01 | |||||||||||||
| 10.18 | NuStar Energy L.P.’s Current Report on Form 8-K filed April 29, 2019 (File No. 001-16417), Exhibit 10.1 | |||||||||||||
108
| Exhibit Number | Description | Incorporated by Reference to the Following Document | ||||||||||||
| 10.19 | NuStar Energy L.P.’s Current Report on Form 8-K filed September 3, 2020 (File No. 001-16417), Exhibit 10.01 | |||||||||||||
| 10.20 | NuStar Energy L.P.’s Current Report on Form 8-K filed January 31, 2022 (File No. 001-16417), Exhibit 10.02 | |||||||||||||
| +10.21 | NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2017 (File No. 001-16417), Exhibit 10.30 | |||||||||||||
| +10.22 | NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2017 (File No. 001-16417), Exhibit 10.31 | |||||||||||||
| +10.23 | NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2016 (File No. 001-16417), Exhibit 10.28 | |||||||||||||
| +10.24 | NuStar Energy L.P.’s Quarterly Report on Form 10-Q for quarter ended September 30, 2018 (File No. 001-16417), Exhibit 10.08 | |||||||||||||
| +10.25 | NuStar GP Holdings, LLC’s Quarterly Report on Form 10-Q for quarter ended June 30, 2007 (File No. 001-32040), Exhibit 10.04 | |||||||||||||
| +10.26 | NuStar GP Holdings, LLC’s Annual Report on Form 10-K for year ended December 31, 2017 (File No. 001-32040), Exhibit 10.46 | |||||||||||||
| +10.27 | NuStar Energy L.P.’s Current Report on Form 8-K filed July 20, 2018 (File No. 001-16417), Exhibit 10.1 | |||||||||||||
| +10.28 | NuStar Energy L.P.’s Quarterly Report on Form 10-Q for quarter ended September 30, 2018 (File No. 001-16417), Exhibit 10.06 | |||||||||||||
| +10.29 | NuStar Energy L.P.’s Current Report on Form 8-K filed April 23, 2019 (File No. 001-16417), Exhibit 10.2 | |||||||||||||
| +10.30 | NuStar Energy L.P.’s Current Report on Form 8-K filed April 23, 2019 (File No. 001-16417), Exhibit 10.3 | |||||||||||||
| +10.31 | NuStar Energy L.P.’s Quarterly Report on Form 10-Q for quarter ended June 30, 2020 (File No. 001-16417), Exhibit 10.11 | |||||||||||||
| +10.32 | NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2020 (File No. 001-16417), Exhibit 10.43 | |||||||||||||
| +10.33 | NuStar Energy L.P.’s Current Report on Form 8-K filed April 30, 2021 (File No. 001-16417), Exhibit 10.1 | |||||||||||||
109
| Exhibit Number | Description | Incorporated by Reference to the Following Document | ||||||||||||
| +10.34 | NuStar Energy L.P.’s Quarterly Report on Form 10-Q for quarter ended June 30, 2021 (File No. 001-16417), Exhibit 10.02 | |||||||||||||
| +10.35 | * | |||||||||||||
| +10.36 | * | |||||||||||||
| +10.37 | NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2006 (File No. 001-16417), Exhibit 10.18 | |||||||||||||
| +10.38 | NuStar Energy L.P.’s Current Report on Form 8-K filed August 4, 2016 (File No. 001-16417), Exhibit 10.1 | |||||||||||||
| +10.39 | NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2015 (File No. 001-16417), Exhibit 10.45 | |||||||||||||
| +10.40 | NuStar Energy L.P.’s Quarterly Report on Form 10-Q for quarter ended September 30, 2018 (File No. 001-16417), Exhibit 10.04 | |||||||||||||
| +10.41 | NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2008 (File No. 001-16417), Exhibit 10.30 | |||||||||||||
| +10.42 | NuStar Energy L.P.’s Quarterly Report on Form 10-Q for quarter ended March 31, 2017 (File No. 001-16417), Exhibit 10.02 | |||||||||||||
| +10.43 | NuStar Energy L.P.’s Quarterly Report on Form 10-Q for quarter ended September 30, 2018 (File No. 001-16417), Exhibit 10.05 | |||||||||||||
| 10.44 | NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2009 (File No. 001-16417), Exhibit 10.24 | |||||||||||||
| 10.45 | NuStar Energy L.P.’s Quarterly Report on Form 10-Q for quarter ended September 30, 2017 (File No. 001-16417), Exhibit 10.02 | |||||||||||||
| 21.01 | * | |||||||||||||
| 22.01 | * | |||||||||||||
| 23.01 | * | |||||||||||||
| 24.01 | * | |||||||||||||
| 31.01 | * | |||||||||||||
| 31.02 | * | |||||||||||||
110
| Exhibit Number | Description | Incorporated by Reference to the Following Document | ||||||||||||
| 32.01 | ** | |||||||||||||
| 32.02 | ** | |||||||||||||
| 101.INS | Inline XBRL Instance Document - The instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document. | * | ||||||||||||
| 101.SCH | Inline XBRL Taxonomy Extension Schema Document | * | ||||||||||||
| 101.CAL | Inline XBRL Taxonomy Extension Calculation Linkbase Document | * | ||||||||||||
| 101.DEF | Inline XBRL Taxonomy Extension Definition Linkbase Document | * | ||||||||||||
| 101.LAB | Inline XBRL Taxonomy Extension Label Linkbase Document | * | ||||||||||||
| 101.PRE | Inline XBRL Taxonomy Extension Presentation Linkbase Document | * | ||||||||||||
| 104 | Cover page Interactive Data File - Formatted in Inline XBRL and contained in Exhibit 101 | * | ||||||||||||
| * | Filed herewith. | ||||
| ** | Furnished herewith. | ||||
| + | Identifies management contracts or compensatory plans or arrangements required to be filed as an exhibit hereto pursuant to Item 15 of Form 10-K. | ||||
An electronic copy of this Form 10-K is available on our website, free of charge, at www.nustarenergy.com
(select the “Investors” link, then the “SEC Filings” link). A paper copy of the Form 10-K also is available without charge to unitholders upon written request at the address below. Copies of exhibits filed as a part of this Form 10-K may be obtained by unitholders of record at a charge of $0.15 per page, minimum $5.00 each request. Direct inquiries to Corporate Secretary, NuStar Energy L.P., 19003 IH-10 West, San Antonio, Texas 78257 or
corporatesecretary@nustarenergy.com.
ITEM 16. FORM 10-K SUMMARY
Not applicable.
111
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Exchange Act, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
| NUSTAR ENERGY L.P. | |||||
| (Registrant) | |||||
| By: | Riverwalk Logistics, L.P., its general partner | ||||
| By: NuStar GP, LLC, its general partner | |||||
| By: | /s/ Bradley C. Barron | ||||
| Bradley C. Barron | |||||
| President and Chief Executive Officer | |||||
| February 24, 2022 | |||||
| By: | /s/ Thomas R. Shoaf | ||||
| Thomas R. Shoaf | |||||
| Executive Vice President and Chief Financial Officer | |||||
| February 24, 2022 | |||||
| By: | /s/ Jorge A. del Alamo | ||||
| Jorge A. del Alamo | |||||
| Senior Vice President and Controller | |||||
| February 24, 2022 | |||||
112
POWER OF ATTORNEY
KNOW ALL MEN BY THESE PRESENTS, that each person whose signature appears below hereby constitutes and appoints Bradley C. Barron, Thomas R. Shoaf and Amy L. Perry, or any of them, each with power to act without the other, his or her true and lawful attorney-in-fact and agent, with full power of substitution and resubstitution, for him or her and in his or her name, place and stead, in any and all capacities, to sign any or all subsequent amendments and supplements to this Annual Report on Form 10-K, and to file the same, or cause to be filed the same, with all exhibits thereto, and other documents in connection therewith, with the Securities and Exchange Commission, granting unto each said attorney-in-fact and agent full power to do and perform each and every act and thing requisite and necessary to be done in and about the premises, as fully to all intents and purposes as he or she might or could do in person, hereby qualifying and confirming all that said attorney-in-fact and agent or his or her substitute or substitutes may lawfully do or cause to be done by virtue hereof.
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated.
| Signature | Title | Date | ||||||
| /s/ William E. Greehey | Chairman of the Board | February 24, 2022 | ||||||
| William E. Greehey | ||||||||
| /s/ Bradley C. Barron | President, Chief Executive | February 24, 2022 | ||||||
| Bradley C. Barron | Officer and Director (Principal Executive Officer) | |||||||
| /s/ Thomas R. Shoaf | Executive Vice President | February 24, 2022 | ||||||
| Thomas R. Shoaf | and Chief Financial Officer (Principal Financial Officer) | |||||||
| /s/ Jorge A. del Alamo | Senior Vice President and Controller | February 24, 2022 | ||||||
| Jorge A. del Alamo | (Principal Accounting Officer) | |||||||
| /s/ J. Dan Bates | Director | February 24, 2022 | ||||||
| J. Dan Bates | ||||||||
| /s/ Jelynne LeBlanc Burley | Director | February 24, 2022 | ||||||
| Jelynne LeBlanc Burley | ||||||||
| /s/ William B. Burnett | Director | February 24, 2022 | ||||||
| William B. Burnett | ||||||||
| /s/ Ed A. Grier | Director | February 24, 2022 | ||||||
| Ed A. Grier | ||||||||
| /s/ Dan J. Hill | Director | February 24, 2022 | ||||||
| Dan J. Hill | ||||||||
| /s/ Robert J. Munch | Director | February 24, 2022 | ||||||
| Robert J. Munch | ||||||||
| /s/ W. Grady Rosier | Director | February 24, 2022 | ||||||
| W. Grady Rosier | ||||||||
| /s/ Martin Salinas, Jr. | Director | February 24, 2022 | ||||||
| Martin Salinas, Jr. | ||||||||
113
Exhibit 4.01
DESCRIPTION OF SECURITIES
NuStar Energy L.P. ("NuStar Energy") has four classes of securities registered under Section 12 of the Securities Exchange Act of 1934, as amended (the "Exchange Act"), each of which is listed on the New York Stock Exchange ("NYSE"), as set forth in the table below.
| Title of Class | Trading Symbol | Exchange | ||||||||||||
| Common Units ("Common Units") | NS | NYSE | ||||||||||||
| Series A Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Units ("Series A Preferred Units") | NSprA | NYSE | ||||||||||||
| Series B Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Units ("Series B Preferred Units") | NSprB | NYSE | ||||||||||||
| Series C Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Units ("Series C Preferred Units") | NSprC | NYSE | ||||||||||||
The following summary of the material terms of our Common Units, Series A Preferred Units, Series B Preferred Units and Series C Preferred Units is based upon our Eighth Amended and Restated Agreement of Limited Partnership, dated as of July 20, 2018 (the "partnership agreement"). The summary is not complete and is qualified by reference to our partnership agreement, which is filed as an exhibit to this Annual Report on Form 10-K and is incorporated herein by reference.
DESCRIPTION OF COMMON UNITS
The Common Units represent limited partner interests that entitle the holders to participate in NuStar Energy’s cash distributions and to exercise the rights and privileges as set forth in the partnership agreement. Please read "The Partnership Agreement" below.
Voting Rights
Each holder of Common Units is entitled to one vote for each unit on all matters submitted to a vote of the Common Unitholders, subject to any limitations contained in NuStar Energy’s partnership agreement. See "The Partnership Agreement—Voting Rights" below.
Cash Distributions
Within 45 days after the end of each quarter, NuStar Energy will distribute all of its available cash to its Common Unitholders of record on the applicable record date.
Available cash is defined in NuStar Energy’s partnership agreement and generally means, with respect to any fiscal quarter, the sum of all cash and cash equivalents at the end of such quarter, plus any cash resulting from working capital borrowings made subsequent to the end of such quarter, less the amount of any cash reserves that NuStar Energy’s general partner determines in its reasonable discretion are necessary or appropriate to:
•provide for the proper conduct of NuStar Energy’s business, including reserves for future capital expenditures and anticipated credit needs;
•comply with applicable law or any debt instrument or other agreement or obligation;
•provide funds for payments to holders of NuStar Energy’s preferred units; or
•provide funds for distributions with respect to any one or more of the next four fiscal quarters.
NuStar Energy’s current policy is, to the extent it has sufficient available cash from operating surplus, as defined in the partnership agreement, to distribute to each Common Unitholder a quarterly distribution of $0.40 per quarter or $1.60 per year. However, there is no guarantee that NuStar Energy will pay a quarterly distribution on the Common Units in any quarter and NuStar Energy may be prohibited from making any distributions to unitholders if it would cause an event of default under the terms of NuStar Energy’s indebtedness. In addition, NuStar Energy’s preferred units rank senior to the Common Units with respect to distribution rights and rights upon liquidation. If NuStar Energy does not pay the required distributions (including any arrears) on its preferred units, it will be unable to pay distributions on the Common Units.
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Exchange Listing
Our outstanding Common Units are listed on the NYSE under the ticker symbol "NS." Any additional Common Units we issue will also be listed on the NYSE.
Transfer Agent and Registrar
Our transfer agent and registrar for the Common Units is Computershare Trust Company, N.A.
DESCRIPTION OF SERIES A, SERIES B AND SERIES C PREFERRED UNITS
The Series A Preferred Units, Series B Preferred Units and Series C Preferred Units (collectively, the "Series A, B and C Preferred Units") represent limited partner interests that entitle the holders to receive cash distributions and to exercise the rights and privileges as set forth in the partnership agreement. Please read "The Partnership Agreement" below.
The following table summarizes the original issuance dates, price per unit, fixed and floating distribution rates and optional redemption dates of our Series A, B and C Preferred Units, as further described below.
| Units | Original Issuance Date | Price per Unit | Fixed Distribution Rate per Annum (as a Percentage of the $25.00 Liquidation Preference per Unit) | Fixed Distribution Rate per Unit per Annum | Optional Redemption Date/Date at Which Distribution Rate Becomes Floating | Floating Annual Rate (as a Percentage of the $25.00 Liquidation Preference per Unit) | ||||||||||||||||||||||||||||||||
| Series A Preferred Units | November 25, 2016 | $ | 25.00 | 8.50 | % | $ | 2.125 | December 15, 2021 | Three-month LIBOR plus 6.766% | |||||||||||||||||||||||||||||
| Series B Preferred Units | April 28, 2017 | $ | 25.00 | 7.625 | % | $ | 1.90625 | June 15, 2022 | Three-month LIBOR plus 5.643% | |||||||||||||||||||||||||||||
| Series C Preferred Units | November 30, 2017 | $ | 25.00 | 9.00 | % | $ | 2.25 | December 15, 2022 | Three-month LIBOR plus 6.88% | |||||||||||||||||||||||||||||
Ranking; Maturity
The Series A, B and C Preferred Units rank senior to NuStar Energy's Common Units with respect to the payment of distributions and distribution of assets upon liquidation, dissolution and winding up. The Series A, B and C Preferred Units rank on parity with each other and with any other securities with terms expressly providing that they rank on parity with the Series A, B and C Preferred Units as to the payment of distributions and distribution of assets upon liquidation, dissolution and winding up, such as NuStar Energy's Series D Cumulative Convertible Preferred Units ("Series D Preferred Units," and collectively with the Series A, B and C Preferred Units, "Preferred Units"). The Series A, B and C Preferred Units have no stated maturity and are not subject to mandatory redemption or any sinking fund and will remain outstanding indefinitely unless repurchased or redeemed by NuStar Energy or converted into its Common Units in connection with a change of control, as described below.
Distributions
Holders of our Series A, B and C Preferred Units are entitled to receive, when, as and if declared by our general partner, out of legally available funds, quarterly cumulative cash distributions. Distributions on the Series A, B and C Preferred Units are cumulative from the original issuance date, and are payable quarterly in arrears on the 15th day of each of March, June, September and December (or the next business day) of each year to holders of record on the first business day of each payment month. Distributions on the Series A, B and C Preferred Units are payable from and including the original issuance date to, but not including, the date at which the distribution rate for each series becomes a floating rate, as set forth in the table above. On and after the date at which the distribution rate for a specific series becomes a floating rate (the "floating rate period"),
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distributions accumulate at a percentage of the $25.00 liquidation preference equal to the annual floating rate set forth in the table above for such series. During the floating rate period, the calculation agent determines LIBOR as provided in the partnership agreement.
Optional Redemption; Conversion
At any time on or after the optional redemption dates set forth in the table above for each of the Series A, B and C Preferred Units, NuStar Energy may, at its option, redeem the Series A, B and C Preferred Units, in whole or in part, out of amounts legally available therefor, by paying $25.00 per unit plus an amount equal to all accumulated and unpaid distributions thereon to the date of redemption, whether or not declared. In addition, NuStar Energy may redeem the Series A, B and C Preferred Units following certain changes of control, as well as at any time within 120 days after the conclusion of any review or appeal process instituted by NuStar Energy following the occurrence of a rating event, each as described in the partnership agreement.
For purposes of the Series A, B and C Preferred Units, a "change of control" generally means the occurrence of either (1) the direct or indirect sale, lease, transfer, conveyance or other disposition (other than by merger, consolidation or business combination), in one or a series of related transactions, of all or substantially all of the assets of NuStar Energy and its subsidiaries taken as a whole to any person or (2) the completion of any transaction (including any merger, consolidation or business combination), the result of which is that any person other than NuStar GP Holdings, LLC and its subsidiaries becomes the direct or indirect beneficial owner of more than 50% of the voting interests in NuStar Energy's general partner and, in the case of either (1) or (2), neither NuStar Energy nor such acquiring person has a class of common equity securities listed or admitted to trading on any National Securities Exchange. A "rating event" generally means a change by any nationally recognized statistical rating organization that publishes a rating for NuStar Energy to its equity credit criteria for securities such as the Series A, B and C Preferred Units, as in effect on the original issuance date of the applicable series (the "current criteria"), which change results in (1) any shortening of the length of time for which the current criteria are scheduled to be in effect with respect to such series or (2) a lower equity credit being given to such series than the equity credit that would have been assigned to such series by such rating agency under the current criteria.
If NuStar Energy does not exercise the option to redeem following a change of control, then the holders of the Series A, B and C Preferred Units have the option to convert their Series A, B and C Preferred Units into a number of Common Units per Series A, B and C Preferred Unit, respectively, as set forth for each such series in the partnership agreement. If NuStar Energy exercises its redemption rights relating to any Series A, B or C Preferred Units following a change of control, the holders of those units will not have the conversion right described above with respect to the units called for redemption.
Voting Rights
Holders of Series A, B and C Preferred Units have only limited voting rights with respect to potential amendments to the partnership agreement that have a material adverse effect on the existing terms of the Series A, B and C Preferred Units, respectively, and in certain other limited circumstances or as required by law. See "The Partnership Agreement—Voting Rights" below.
Exchange Listing
Our outstanding Series A, B and C Preferred Units are listed on the NYSE under the ticker symbols "NSprA," "NSprB" and "NSprC," respectively. Any additional Series A, B and C Preferred Units we issue will also be listed on the NYSE.
Calculation Agent
In the case of the Series A Preferred Units and the Series B Preferred Units, the calculation agent will be Wells Fargo Bank, National Association and its successors and assigns or any other calculation agent appointed by NuStar Energy's general partner. In the case of the Series C Preferred Units, the calculation agent will be the person appointed by NuStar Energy's general partner before the start of the floating rate period for the Series C Preferred Units, and its successors and assigns or any other calculation agent appointed by NuStar Energy's general partner.
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THE PARTNERSHIP AGREEMENT
The material provisions of NuStar Energy's partnership agreement are summarized below.
Organization and Duration
NuStar Energy was organized in December 1999 and will continue in existence until dissolved in accordance with the partnership agreement.
Purpose
The purpose of NuStar Energy is: (1) to serve as a partner of NuStar Logistics, one of NuStar Energy’s primary operating subsidiaries, and its other subsidiaries established for conducting the business of NuStar Energy (collectively, the "Operating Partnership"); (2) to engage in any business activities that may be engaged in by the Operating Partnership or that are approved by NuStar Energy’s general partner, provided that NuStar Energy’s general partner must reasonably determine that such activity generates or enhances the operations of any activity that generates "qualifying income," as this term is defined in Section 7704 of the Internal Revenue Code of 1986, as amended; (3) to serve as a member of NuStar GP Holdings, LLC and to exercise all the rights and powers held by NuStar Energy as a member of NuStar GP Holdings, LLC as the member of NuStar GP, LLC; and (4) to do anything necessary or appropriate to the foregoing, including the making of capital contributions or loans to NuStar Energy’s subsidiaries. NuStar Energy’s general partner has no obligation or duty to NuStar Energy, its limited partners or assignees of partnership interests to propose or approve, and in its discretion may decline to propose or approve, the conduct by NuStar Energy of any business.
Power of Attorney
Each limited partner, and each person who acquires a limited partner interest and executes and delivers a transfer application, grants to NuStar Energy’s general partner and, if appointed, a liquidator, a power of attorney to, among other things, execute and file documents required for the qualification, continuance or dissolution of NuStar Energy. The power of attorney also grants NuStar Energy’s general partner and the liquidator the authority to amend the partnership agreement, and to make consents and waivers under the partnership agreement.
Capital Contributions
NuStar Energy’s unitholders are not obligated to make additional capital contributions, except as described below under "—Limited Liability."
Limited Liability
Assuming that a limited partner does not participate in the control of NuStar Energy’s business within the meaning of the Delaware Revised Uniform Limited Partnership Act (the "Delaware law"), and that it otherwise acts in conformity with the provisions of NuStar Energy’s partnership agreement, the limited partner’s liability under the Delaware law will be limited, subject to possible exceptions, to the amount of capital the limited partner is obligated to contribute to NuStar Energy for such partner’s units plus the partner’s share of any undistributed profits and assets and any funds wrongfully distributed to it, as described below. If it were determined, however, that the right or exercise of the right, by the limited partners as a group:
•to remove or replace NuStar Energy’s general partner;
•to approve some amendments to the partnership agreement; or
•to take other action under the partnership agreement
constituted "participation in the control" of NuStar Energy’s business for the purposes of the Delaware law, then the limited partners could be held personally liable for NuStar Energy’s obligations under the laws of Delaware, to the same extent as its general partner. This liability would extend to persons who transact business with NuStar Energy who reasonably believe that a limited partner is a general partner based on the limited partner’s conduct.
Neither NuStar Energy’s partnership agreement nor the Delaware law specifically provides for legal recourse against NuStar Energy’s general partner if a limited partner were to lose limited liability through any fault of NuStar Energy’s general partner. While this does not mean that a limited partner could not seek legal recourse, we know of no precedent for this type of a claim in Delaware case law.
Under the Delaware law, a limited partnership may not make a distribution to a partner if, after the distribution, all liabilities of the limited partnership, other than liabilities to partners on account of their partnership interests and liabilities for which the
4
recourse of creditors is limited to specific property of the partnership, would exceed the fair value of the assets of the limited partnership. For the purpose of determining the fair value of the assets of a limited partnership, the Delaware law provides that the fair value of property subject to liability for which recourse of creditors is limited shall be included in the assets of the limited partnership only to the extent that the fair value of that property exceeds the nonrecourse liability. The Delaware law provides that a limited partner who receives a distribution and knew at the time of the distribution that the distribution was in violation of the Delaware law will be liable to the limited partnership for the amount of the distribution for three years from the date of distribution. Under the Delaware law, an assignee who becomes a substituted limited partner of a limited partnership is liable for the obligations of its assignor to make contributions to the limited partnership, excluding any obligations of the assignor with respect to wrongful distributions, as described above, except the assignee is not obligated for liabilities unknown to it at the time it became a limited partner and that could not be ascertained from the partnership agreement.
NuStar Energy’s operating subsidiaries conduct business or own assets in the United States and internationally. Maintenance of NuStar Energy’s limited liability as a limited partner or member, respectively, of its operating subsidiaries may require compliance with legal requirements in the jurisdictions in which the operating subsidiary conducts business. Limitations on the liability of limited partners or members for the obligations of a limited partnership or limited liability company have not been clearly established in many jurisdictions. If it were determined that NuStar Energy was, by virtue of NuStar Energy’s ownership interest in its subsidiaries or otherwise, conducting business in any state without compliance with the applicable limited partnership or limited liability company statute, or that the right or exercise of the right by the limited partners as a group to remove or replace NuStar Energy’s general partner, to approve certain amendments to the partnership agreement, or to take other action under the partnership agreement constituted "participation in the control" of NuStar Energy’s business for purposes of the statutes of any relevant jurisdiction, then the limited partners could be held personally liable for NuStar Energy’s obligations under the law of that jurisdiction to the same extent as its general partner under the circumstances. NuStar Energy will operate in a manner that its general partner considers reasonable and necessary or appropriate to preserve the limited liability of the limited partners.
Voting Rights
The following matters require the unitholder vote specified below. Matters that require the approval of a "unit majority" require the approval of holders of a majority of the outstanding Common Units and the outstanding Series D Preferred Units (voting on an as-converted basis), voting together as a single class (subject to the limitations set forth in the definition of "Outstanding" in the partnership agreement).
| Election of directors to the board | Plurality of the votes cast by the limited partners holding outstanding Common Units and Series D Preferred Units (voting on an as-converted basis), voting together as a single class, at a meeting of the limited partners. Please read "—Meetings; Voting." | ||||
| Amendment of the partnership agreement | Certain amendments may be made by NuStar Energy’s general partner without the approval of unitholders. Certain other amendments require the approval of a unit majority. Certain other amendments require the approval of the holders of a super-majority of outstanding Common Units and Series D Preferred Units (voting on an as-converted basis), voting together as a single class. Certain amendments that would have a material adverse effect on a class of NuStar Energy interests require the approval of a majority of NuStar Energy interests to be affected by such amendment. Please read "—Amendment of the Partnership Agreement." | ||||
| Merger or the sale of all or substantially all of NuStar Energy’s assets | The holders of a unit majority. Please read "—Merger, Sale or Other Disposition of Assets." | ||||
| Dissolution of NuStar Energy | The holders of a unit majority. Please read "—Termination and Dissolution." | ||||
| Removal/Replacement of the general partner | The holders of a unit majority. Please read "—Withdrawal or Removal of the General Partner." | ||||
5
Issuance of Additional Securities
NuStar Energy’s partnership agreement authorizes NuStar Energy, subject to any approvals required by the holders of Preferred Units, to issue an unlimited number of additional partnership securities for the consideration and on the terms and conditions established by NuStar Energy’s general partner in its sole discretion without the approval of any limited partners.
Except for restrictions arising from the need for approval of the holders of Preferred Units, there are no restrictions under the partnership agreement on the ability of NuStar Energy’s general partner to issue partnership securities, including partnership securities junior or senior to the Common Units.
It is possible that NuStar Energy will fund acquisitions through the issuance of additional Common Units or other partnership securities. Holders of any additional Common Units NuStar Energy issues will be entitled to share equally with the then-existing Common Unitholders in NuStar Energy’s distributions of available cash and additional partnership securities may be senior to the Common Units with respect to distributions. In addition, the issuance of additional partnership securities may dilute the value of the interests of the then-existing Common Unitholders in NuStar Energy’s net assets.
In accordance with Delaware law and the provisions of the partnership agreement, NuStar Energy may also issue additional partnership securities that, in the sole discretion of NuStar Energy’s general partner, may have special voting rights to which Common Units are not entitled.
No person will have any preemptive, preferential or other similar right with respect to the issuance of any partnership securities.
Amendment of the Partnership Agreement
General
Amendments to the partnership agreement may be proposed only by or with the consent of NuStar Energy’s general partner, which consent may be given or withheld in its sole discretion. In order to adopt a proposed amendment, other than the amendments discussed below, NuStar Energy’s general partner is required to seek written approval of the holders of the number of units required to approve the amendment or call a meeting of the limited partners to consider and vote upon the proposed amendment. Except as described below, an amendment must be approved by a unit majority.
Prohibited Amendments
No amendment may be made that would:
•amend, alter, change, repeal or rescind, in any respect, a provision of the partnership agreement that establishes a percentage of outstanding units required to take any action, that would have the effect of reducing such voting percentage, unless such amendment is approved by the written consent or the affirmative vote of holders of outstanding units whose aggregate outstanding units constitute not less than the voting requirement sought to be reduced;
•enlarge the obligations of any limited partner without its consent, unless approved by at least a majority of the type or class of limited partner interests so affected;
•enlarge the obligations of, restrict in any way any action by or rights of, or reduce in any way the amounts distributable, reimbursable or otherwise payable by NuStar Energy to its general partner or any of its affiliates without the consent of NuStar Energy’s general partner, which may be given or withheld in its sole discretion;
•change the term of NuStar Energy;
•provide that NuStar Energy is not dissolved upon an election to dissolve NuStar Energy by its general partner that is approved by the holders of a unit majority;
•give any person the right to dissolve NuStar Energy, other than its general partner’s right to dissolve NuStar Energy with the approval of the holders of a unit majority; or
•have a material adverse effect on the rights or preferences of any class of partnership securities in relation to other classes of partnership securities, unless approved by the holders of not less than a majority of the outstanding partnership securities of the class affected.
The provision of the partnership agreement prohibiting amendments to the partnership agreement having the effects described in the seven bullets above can be amended, subject to certain exceptions, only upon the approval of the holders of at least 90% of the outstanding Common Units and Series D Preferred Units (voting on an as-converted basis), voting together as a single class. In addition, no amendment may be made to the partnership agreement that would have a material adverse effect on the powers, preferences, duties or special rights of the Preferred Units without first obtaining the affirmative vote or consent of the
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holders of (a) 66-2/3% of the respective outstanding class of Series A Preferred Units, Series B Preferred Units and Series C Preferred Units or (b) a majority of the outstanding Series D Preferred Units.
No Unitholder Approval
NuStar Energy’s general partner may generally make amendments to the partnership agreement without the approval of any partner or assignee to reflect:
•a change in the name of NuStar Energy, the location of the principal place of business of NuStar Energy, the registered agent or the registered office of NuStar Energy;
•the admission, substitution, withdrawal or removal of partners in accordance with the partnership agreement;
•a change that, in the sole discretion of NuStar Energy’s general partner, is necessary or advisable to qualify or continue the qualification of NuStar Energy as a limited partnership or a partnership in which the limited partners have limited liability under the laws of any state or to ensure that neither NuStar Energy nor the Operating Partnership will be treated as an association taxable as a corporation or otherwise taxed as an entity for federal income tax purposes;
•an amendment that is necessary, in the opinion of counsel to NuStar Energy, to prevent NuStar Energy, its general partner, NuStar GP, LLC, or any of the directors, officers, agents or trustees of NuStar GP, LLC from in any manner being subjected to the provisions of the Investment Company Act of 1940, the Investment Advisors Act of 1940, or "plan asset" regulations adopted under the Employee Retirement Income Security Act of 1974, as amended ("ERISA"), whether or not substantially similar to plan asset regulations currently applied or proposed;
•subject to any restrictions imposed by the terms of the Preferred Units and the limitations on the issuance of additional partnership securities described above, an amendment that in the discretion of NuStar Energy’s general partner is necessary or advisable for the authorization of additional partnership securities;
•any amendment expressly permitted in the partnership agreement to be made by NuStar Energy’s general partner acting alone;
•an amendment effected, necessitated or contemplated by a merger agreement that has been approved under the terms of the partnership agreement;
•any amendment that, in the discretion of NuStar Energy’s general partner, is necessary or advisable for the formation by NuStar Energy of, or its investment in, any corporation, partnership or other entity, as otherwise permitted by the partnership agreement;
•a change in the fiscal year or taxable year of NuStar Energy and related changes; and
•any other amendments substantially similar to any of the matters described above.
In addition, subject to any restrictions imposed by the terms of the Preferred Units, NuStar Energy’s general partner may make amendments to the partnership agreement without the approval of any partner or assignee if those amendments, in the discretion of NuStar Energy’s general partner:
•do not adversely affect the limited partners (or any particular class of limited partners) in any material respect;
•are necessary or advisable to satisfy any requirements, conditions or guidelines contained in any opinion, directive, order, ruling or regulation of any federal or state agency or judicial authority or contained in any federal or state statute;
•are necessary or advisable to facilitate the trading of limited partner interests or to comply with any rule, regulation, guideline or requirement of any securities exchange on which the limited partner interests are or will be listed for trading, compliance with any of which NuStar Energy’s general partner deems to be in the best interests of NuStar Energy and the limited partners;
•are necessary or advisable for any action taken by NuStar Energy’s general partner relating to splits or combinations of partnership securities under the provisions of the partnership agreement; or
•are required to effect the intent of the provisions of the partnership agreement or are otherwise contemplated by the partnership agreement.
Opinion of Counsel and Unitholder Approval
Except for amendments described above under "—No Unitholder Approval" or in connection with a merger, no other amendments to the partnership agreement will become effective without the approval of holders of at least 90% of the outstanding Common Units and Series D Preferred Units (voting on an as-converted basis), voting together as a single class, unless NuStar Energy obtains an opinion of counsel to the effect that the amendment will not affect the limited liability of any limited partner of NuStar Energy under applicable law.
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Merger, Sale or Other Disposition of Assets
Subject to certain exceptions, a merger or consolidation of NuStar Energy requires the prior approval of NuStar Energy’s general partner. NuStar Energy’s general partner must also approve the merger agreement, which must include certain information as set forth in NuStar Energy’s partnership agreement. Once approved by NuStar Energy’s general partner, the merger agreement must be submitted to a vote of Common Unitholders and Series D Preferred Unitholders (voting on an as-converted basis), voting together as a single class, and the merger agreement will be approved upon receipt of the affirmative vote or consent of the holders of a unit majority (unless the affirmative vote of the holders of a greater percentage is required under the merger agreement or Delaware law).
Except in connection with a dissolution and liquidation of NuStar Energy or a duly approved merger, NuStar Energy’s general partner may not (a) sell, exchange or otherwise dispose of all or substantially all of NuStar Energy’s assets in a single transaction or a series of related transactions, or (b) approve on behalf of NuStar Energy the sale, exchange or other disposition of all or substantially all of the assets of the Operating Partnership without the approval of the holders of a unit majority. However, NuStar Energy’s general partner may mortgage, pledge, hypothecate or grant a security interest in all or substantially all of the assets of NuStar Energy or the Operating Partnership without the approval of the unitholders. In addition, NuStar Energy’s general partner may sell any or all of the assets of NuStar Energy or the Operating Partnership in a forced sale pursuant to the foreclosure of, or other realization upon, any such encumbrance without the approval of the unitholders.
Termination and Dissolution
NuStar Energy will continue in existence as a limited partnership until terminated in accordance with its partnership agreement. NuStar Energy will dissolve upon:
•the election of NuStar Energy’s general partner to dissolve NuStar Energy, if approved by the holders of a unit majority;
•the entry of a decree of judicial dissolution of NuStar Energy pursuant to Delaware law;
•the sale of all or substantially all of the assets and properties of NuStar Energy, the Operating Partnership and their respective subsidiaries; or
•the withdrawal or removal of NuStar Energy’s general partner or any other event that results in its ceasing to be the general partner other than by reason of a transfer of its general partner interest in accordance with the partnership agreement or withdrawal or removal following approval and admission of a successor.
Upon a dissolution under the last clause above, the holders of a unit majority may also elect, within specific time limitations, to reconstitute NuStar Energy and continue its business on the same terms and conditions described in the partnership agreement by forming a new limited partnership on terms identical to those in the partnership agreement and having as general partner an entity approved by the holders of a unit majority, subject to receipt by NuStar Energy of an opinion of counsel to the effect that:
•the action would not result in the loss of limited liability of any limited partner; and
•neither NuStar Energy, the reconstituted limited partnership, nor any operating subsidiary would be treated as an association taxable as a corporation or otherwise be taxable as an entity for federal income tax purposes upon the exercise of that right to continue.
Liquidation and Distribution of Proceeds
Upon its dissolution, unless NuStar Energy is reconstituted and continued as a new limited partnership, the liquidator authorized to wind up NuStar Energy’s affairs will, acting with all of the powers of NuStar Energy’s general partner that the liquidator deems necessary or desirable in its judgment, liquidate NuStar Energy’s assets and apply the proceeds of the liquidation as follows. NuStar Energy will first apply the proceeds of liquidation to the payment of, or provision of payment for, its creditors. NuStar Energy will then pay any accumulated and unpaid distributions and the applicable liquidation preference on the Preferred Units. NuStar Energy will distribute any remaining proceeds to Common Unitholders, in accordance with their capital account balances, as adjusted to reflect any gain or loss upon the sale or other disposition of its assets in liquidation. The liquidator may defer liquidation or distribution of NuStar Energy’s assets for a reasonable period of time or distribute assets to partners in kind if it determines that a sale would be impractical or would cause undue loss to the partners.
Withdrawal or Removal of the General Partner
NuStar Energy’s general partner may withdraw as general partner without first obtaining approval of any unitholder by giving 90 days’ written notice, and that withdrawal will not constitute a violation of the partnership agreement. In addition, the
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partnership agreement permits NuStar Energy’s general partner to sell or otherwise transfer all of its general partner interest in NuStar Energy without the approval of the unitholders. Please read "—Transfer of General Partner Interests."
Upon the withdrawal of NuStar Energy’s general partner under any circumstances, other than as a result of a transfer of all or a part of its general partner interest in NuStar Energy, the holders of a unit majority may select a successor to that withdrawing general partner. If a successor is not elected, or is elected but an opinion of counsel regarding limited liability and tax matters cannot be obtained, NuStar Energy will be dissolved, wound up and liquidated, unless within 180 days after that withdrawal, the holders of a unit majority agree in writing to continue the business of NuStar Energy and to appoint a successor general partner. Please read "—Termination and Dissolution."
If NuStar Energy’s general partner withdraws under circumstances where such withdrawal does not violate the partnership agreement, and a successor general partner is elected under the terms of the partnership agreement, the departing general partner will have the option to require the successor general partner to purchase its general partner interests for cash. If NuStar Energy’s general partner withdraws under circumstances where such withdrawal does violate the partnership agreement, and a successor general partner is elected, the successor general partner will have the option to purchase the general partner interests of the departing general partner. If such general partner interests are not purchased by the successor general partner, they will be converted into Common Units.
NuStar Energy’s general partner may not be removed unless that removal is approved by the vote of the holders of not less than a unit majority, and NuStar Energy receives an opinion of counsel regarding limited liability and tax matters. Any removal of NuStar Energy’s general partner is also subject to the approval of a successor general partner by the vote of a unit majority.
If NuStar Energy’s general partner is removed under circumstances where cause does not exist, and a successor general partner is elected under the partnership agreement, the departing general partner will have the option to require the successor general partner to purchase its general partner interests for cash. If NuStar Energy’s general partner is removed under circumstances where cause does exist, and a successor general partner is elected, the successor general partner will have the option to purchase the general partner interests of the departing general partner. If NuStar Energy’s general partner interests are not purchased by the successor general partner, they will be converted into Common Units.
"Cause" is narrowly defined to mean that a court of competent jurisdiction has entered a final, non-appealable judgment finding the general partner liable for actual fraud, gross negligence, or willful or wanton misconduct in its capacity as the general partner.
Withdrawal or removal of the general partner of NuStar Energy also constitutes withdrawal or removal of the general partner of the Operating Partnership.
In addition, NuStar Energy will be required to reimburse the departing general partner for all amounts due the departing general partner, including, without limitation, all employee-related liabilities, including severance liabilities, incurred for the termination of any employees employed by the departing general partner for the benefit of NuStar Energy.
Transfer of General Partner Interests
NuStar Energy’s general partner may transfer all or any part of its general partner interest in NuStar Energy without unitholder approval.
No transfer by NuStar Energy’s general partner of all or any part of its general partner interest is permitted unless (1) the transferee agrees to assume the rights and duties of the general partner and be bound by the partnership agreement, (2) NuStar Energy receives an opinion of counsel regarding limited liability and tax matters and (3) such transferee agrees to purchase all of the partnership interests of the general partner as the general partner of the Operating Partnership and any of NuStar Energy’s or the Operating Partnership’s subsidiaries.
Change of Management Provisions
NuStar Energy’s partnership agreement contains specific provisions that are intended to discourage a person or group from attempting to remove NuStar Energy’s general partner or otherwise change management, including the following:
•with certain limited exceptions, any partnership securities held by a person that owns 20% or more of any class of partnership securities then outstanding, other than NuStar Energy’s general partner and its affiliates, cannot be voted on any matter; provided, however that such restriction generally does not apply to any Series D Preferred Units held by a person who acquired such Series D Preferred Units pursuant to the Series D Cumulative Convertible Preferred Unit Purchase Agreement, dated as of June 26, 2018, among NuStar Energy L.P. and the purchasers party thereto;
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•limiting the ability of unitholders to replace members of the board of directors of NuStar GP, LLC (the “board”) by having staggered elections where each director is elected for a three-year term and providing that directors may only be removed for cause; and
•limiting the ability of unitholders to call meetings or to acquire information about NuStar Energy’s operations, as well as other provisions limiting the unitholders’ ability to influence the manner or direction of management.
Meetings; Voting
An annual meeting of the limited partners for the election of directors to the board, and other matters that NuStar Energy’s general partner submits to a vote of the limited partners, will be held in April of each year or on such other date as determined by NuStar Energy’s general partner. Special meetings of the limited partners may be called by NuStar Energy’s general partner or by limited partners owning 20% or more of the outstanding limited partner interests of the class or classes for which a meeting is proposed.
For the purpose of determining the limited partners entitled to notice of or to vote at any meeting or to give approvals without a meeting, NuStar Energy’s general partner may set a record date, which date for purposes of notice of a meeting shall not be less than 10 days nor more than 60 days before the date of the meeting.
Each record holder of limited partner interests has a vote according to his percentage interest in NuStar Energy. Limited partner interests held for a person’s account by another person (such as a broker, dealer or bank), in whose name such limited partner interests are registered, will be voted by such other person in favor of, and at the direction of, the beneficial owner unless the arrangement between such persons provides otherwise. Representation in person or by proxy of a majority of the outstanding limited partner interests of the class or classes for which a meeting has been called will constitute a quorum at such meeting (unless a particular action by the limited partners requires approval by a greater percentage of limited partner interests, in which case the quorum shall be such greater percentage).
At any meeting at which a quorum is present, the act of the limited partners holding a majority of the outstanding limited partner interests entitled to vote at the meeting will be deemed to be the act of all the limited partners, unless a greater or different percentage is required under the partnership agreement, in which case the act of the limited partners holding such greater or different percentage of the outstanding limited partner interests will be required. At a meeting for the election of directors, directors are elected by a plurality of votes cast by the limited partners holding outstanding Common Units and Series D Preferred Units (voting on an as-converted basis), voting together as a single class.
If authorized by NuStar Energy’s general partner, any action that is required or permitted to be taken at a meeting of the limited partners may be taken either at a meeting of the limited partners or without a meeting if consents in writing describing the action so taken are signed by the holders of the number of limited partner interests necessary to authorize or take that action at a meeting.
The Board of Directors
The number of directors on the board will be nine unless otherwise determined from time to time by a majority of the directors then in office or automatically increased pursuant to the terms of the Series D Preferred Units. Any decrease in the number of directors by the board may not have the effect of shortening the term of any incumbent director.
The directors are grouped into three groups with respect to their terms. At each annual meeting of limited partners, successors to the directors whose terms expire at that annual meeting will be elected for a three-year term.
A director may only be removed for cause at a meeting of limited partners upon the affirmative vote of the limited partners holding a unit majority and only if, at the same meeting, the limited partners holding a unit majority nominate a replacement director and elect the replacement director to the board. Vacancies on the board (other than vacancies caused by the removal of a director by the limited partners) may be filled by a majority of the remaining directors then in office.
Nominations of persons for election as directors to the board may be made at an annual meeting of the limited partners only pursuant to NuStar Energy’s general partner’s notice of meeting (1) by or at the direction of a majority of the directors of the board or (2) by a limited partner, or a group of limited partners, that holds or beneficially owns, and has continuously held or beneficially owned without interruption for the prior two years, 5% of the outstanding Common Units and outstanding Series D Preferred Units (on an as-converted basis), considered together for this purpose as a single class, and such limited partner, or each limited partner in such group, (A) was a limited partner at the time the notice provided for in the partnership agreement is delivered to NuStar Energy’s general partner and (B) complies with the notice procedures set forth in the partnership agreement.
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For any nominations brought before an annual meeting by a limited partner, the limited partner must give timely notice thereof in writing to NuStar Energy’s general partner. The notice must contain certain information as described in the partnership agreement. To be timely, a limited partner’s notice must be delivered to NuStar Energy’s general partner not later than the close of business on the 90th day, nor earlier than the close of business on the 120th day, prior to the first anniversary of the preceding year’s annual meeting. The public announcement of an adjournment or postponement of an annual meeting will not commence a new time period (or extend any time period) for the giving of a limited partner’s notice as described above.
In the event that the number of directors is increased effective after the time period for which nominations would otherwise be due and there is no public announcement by NuStar Energy or its general partner naming the nominees for the additional directorships at least 100 days prior to the first anniversary of the preceding year’s annual meeting, a limited partner’s notice will also be considered timely with respect to nominees for the additional directorships, if it is delivered to NuStar Energy’s general partner not later than the close of business on the 10th day following the day on which such public announcement is first made by NuStar Energy or its general partner.
Nominations for directors may be made at a special meeting of limited partners at which directors are to be elected in accordance with the provisions of the partnership agreement.
Only persons who are nominated in accordance with the procedures set forth in the partnership agreement will be eligible to be elected at an annual or special meeting of limited partners to serve as directors. Unless otherwise required by law or the partnership agreement, if each nominating limited partner does not appear at the annual or special meeting of limited partners to present a nomination, the nomination will be disregarded.
In addition to the provisions described above and in the partnership agreement, a limited partner must also comply with all applicable requirements of the Exchange Act and the rules and regulations thereunder. Any references in the partnership agreement to the Exchange Act or the rules promulgated thereunder are not intended to, and do not, limit any requirements applicable to nominations pursuant to the partnership agreement, and compliance with the partnership agreement is the exclusive means for a limited partner to make nominations.
Limited Call Right
If at any time NuStar Energy’s general partner and its affiliates own 80% or more of the issued and outstanding limited partner interests of any class, NuStar Energy’s general partner will have the right (which right it may assign and transfer to NuStar Energy or any affiliate of its general partner) to purchase all, but not less than all, of the outstanding limited partner interests of that class that are held by non-affiliated persons. The record date for determining ownership of the limited partner interests to be purchased by NuStar Energy’s general partner will be selected by NuStar Energy’s general partner, and NuStar Energy’s general partner must mail notice of its election to purchase the interests to the holders of such interests at least 10 but not more than 60 days prior to the purchase date. The purchase price in the event of a purchase under these provisions would be the greater of (1) the current market price (as defined in the partnership agreement) of the limited partner interests of the class as of the date three days prior to the date NuStar Energy’s general partner mails notice of its election to purchase the limited partner interests and (2) the highest cash price paid by NuStar Energy’s general partner or any of its affiliates for any limited partner interest of the class purchased within the 90 days preceding the date NuStar Energy’s general partner mails notice of its election to purchase the limited partner interests.
Transfer of Limited Partner Interests and Status as a Limited Partner or Assignee
No transfer of NuStar Energy limited partner interests represented by certificates will be recognized by NuStar Energy unless certificates representing those limited partner interests are surrendered and such certificates are accompanied by a duly executed transfer application. Each transferee of limited partner interests must execute a transfer application whereby the transferee, among other things, requests admission as a substituted limited partner, makes certain representations, executes and agrees to comply with and be bound by the partnership agreement, and gives the consents and approvals and makes the waivers contained in the partnership agreement. Transferees may hold limited partner interests in nominee accounts.
Once a transferee has executed and delivered a transfer application in accordance with the partnership agreement, the transferee becomes an assignee. An assignee becomes a limited partner upon the consent of NuStar Energy’s general partner and the recordation of the name of the assignee on NuStar Energy’s books and records. Such consent may be withheld in the sole discretion of NuStar Energy’s general partner. An assignee, pending its admission as a substituted limited partner, is entitled to an interest in NuStar Energy equivalent to that of a limited partner with respect to the right to share in allocations and distributions, including liquidating distributions of NuStar Energy. NuStar Energy’s general partner will vote and exercise, at the written direction of the assignee, other powers attributable to limited partner interests owned by an assignee who has not become a substituted limited partner.
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Transferees who do not execute and deliver transfer applications will be treated neither as assignees nor as record holders of limited partner interests and will not receive distributions, federal income tax allocations or reports furnished to record holders of limited partner interests. The only right such transferees will have is the right to admission as a substituted limited partner upon execution of a transfer application, subject to the approval of NuStar Energy’s general partner. A nominee or broker who has executed a transfer application with respect to limited partner interests held in street name or nominee accounts will receive distributions and reports pertaining to such limited partner interests.
Non-Citizen Assignees; Redemption
If NuStar Energy, the Operating Partnership or any of their respective subsidiaries is or becomes subject to federal, state or local laws or regulations that, in the reasonable determination of NuStar Energy’s general partner, create a substantial risk of cancellation or forfeiture of any property that NuStar Energy, the Operating Partnership or any of their respective subsidiaries has an interest in because of the nationality, citizenship or other related status of any limited partner or assignee, NuStar Energy may redeem the limited partner interests held by the limited partner or assignee at their current market price. In order to avoid any cancellation or forfeiture, NuStar Energy’s general partner may require each limited partner or assignee to furnish information about his nationality, citizenship or related status. If a limited partner or assignee fails to furnish information about this nationality, citizenship or other related status within 30 days after a request for the information or NuStar Energy’s general partner determines after receipt of the information that the limited partner or assignee is not an eligible citizen, the limited partner or assignee may be treated as a non-citizen assignee. In addition to other limitations on the rights of an assignee who is not a substituted limited partner, a non-citizen assignee does not have the right to direct the voting of his limited partner interests and may not receive distributions in kind upon NuStar Energy’s liquidation.
Indemnification
Under the partnership agreement, in most circumstances, NuStar Energy will indemnify the following persons, to the fullest extent permitted by law, from and against all losses, claims, damages or similar events as long as such persons acted in good faith and in a manner they reasonably believed to be in or not opposed to the best interests of NuStar Energy, and, with respect to any criminal proceeding, had no reasonable cause to believe their conduct was unlawful:
•NuStar Energy’s general partner;
•any departing general partner;
•any person who is or was an affiliate of NuStar Energy’s general partner or any departing general partner;
•any person who is or was a member, partner, officer, director, employee, agent or trustee of NuStar Energy, the Operating Partnership or any of their respective subsidiaries, NuStar Energy’s general partner or any departing general partner or any affiliate of NuStar Energy, the Operating Partnership, their respective subsidiaries, NuStar Energy’s general partner or any departing general partner; or
•any person who is or was serving at the request of NuStar Energy’s general partner or departing general partner or any affiliate of NuStar Energy’s general partner or departing general partner as an officer, director, employee, member, partner, agent, fiduciary or trustee of another person.
Any indemnification under these provisions will only be out of NuStar Energy’s assets. NuStar Energy’s general partner will not be personally liable for any of NuStar Energy’s indemnification obligations, or have any obligation to contribute or loan funds or assets to NuStar Energy to enable it to effectuate indemnification. NuStar Energy is authorized to purchase insurance against liabilities asserted against and expenses incurred by persons for its activities, regardless of whether NuStar Energy would have the power to indemnify the person against liabilities under the partnership agreement.
Books and Reports
NuStar Energy’s general partner is required to keep appropriate books of NuStar Energy’s business at NuStar Energy’s principal offices. The books will be maintained for both tax and financial reporting purposes on an accrual basis. For tax and financial reporting purposes, NuStar Energy’s fiscal year is the calendar year.
NuStar Energy will furnish or make available to record holders of partnership securities, within 120 days after the close of each fiscal year, an annual report containing audited financial statements and a report on those financial statements by its registered public accounting firm. Except for its fourth quarter, NuStar Energy will also furnish or make available summary financial information within 90 days after the close of each quarter.
NuStar Energy will furnish each record holder of a partnership security with information reasonably required for tax reporting purposes within 90 days after the close of each calendar year.
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Right to Inspect NuStar Energy’s Books and Records
The partnership agreement provides that a limited partner can, for a purpose reasonably related to such limited partner’s interest as a limited partner, upon reasonable demand and at its own expense, have furnished to it:
•information regarding the status of the business and financial condition of NuStar Energy;
•a copy of NuStar Energy’s tax returns;
•a current list of the name and last known address of each partner;
•copies of the partnership agreement, the certificate of limited partnership of NuStar Energy, related amendments and powers of attorney under which they have been executed;
•information as to the amount of cash, and a description and statement of the agreed value of any other property or services, contributed or to be contributed by each partner and the date on which each became a partner;
•any other information regarding NuStar Energy’s affairs as is just and reasonable.
NuStar Energy’s general partner may, and intends to, keep confidential from the limited partners trade secrets or other information the disclosure of which it believes in good faith is not in NuStar Energy’s, the Operating Partnership’s and their respective subsidiaries’ best interests, could damage NuStar Energy, the Operating Partnership and their respective subsidiaries or which NuStar Energy, the Operating Partnership or their respective subsidiaries are required by law or by agreements with third parties to keep confidential.
Registration Rights
Under the partnership agreement, NuStar Energy has agreed to register for resale under the Securities Act of 1933, as amended, and applicable state securities laws any Common Units or other partnership securities proposed to be sold by the general partner or any of its affiliates or their assignees if an exemption from the registration requirements is not otherwise available. These registration rights continue for two years following any withdrawal or removal of Riverwalk Logistics, L.P. as the general partner of NuStar Energy. NuStar Energy is obligated to pay all expenses incidental to the registration, excluding underwriting discounts and commissions.
Conflicts of Interest
Riverwalk Logistics, L.P., the general partner of NuStar Energy, has a legal duty to manage NuStar Energy in a manner beneficial to NuStar Energy’s unitholders. This legal duty originates in statutes and judicial decisions and is commonly referred to as a "fiduciary" duty.
NuStar Energy’s partnership agreement contains provisions that allow its general partner to take into account the interests of parties in addition to NuStar Energy in resolving conflicts of interest. In effect, these provisions limit NuStar Energy’s general partner’s fiduciary duties to the unitholders. The partnership agreement also restricts the remedies available to unitholders for actions taken that might, without those limitations, constitute breaches of fiduciary duty. Whenever a conflict arises between NuStar Energy’s general partner or its affiliates, on the one hand, and NuStar Energy or any other partner, on the other hand, NuStar Energy’s general partner will resolve that conflict.
NuStar Energy’s general partner will not be in breach of its obligations under the partnership agreement or its duties to NuStar Energy or the unitholders if the resolution of the conflict is considered to be fair and reasonable to NuStar Energy. Any resolution is considered to be fair and reasonable to NuStar Energy if that resolution is:
•approved by a conflicts committee consisting of three or more independent directors of NuStar GP, LLC, although no party is obligated to seek approval and NuStar Energy’s general partner may adopt a resolution or course of action that has not received approval;
•on terms no less favorable to NuStar Energy than those generally being provided to or available from unrelated third parties; or
•fair to NuStar Energy, taking into account the totality of the relationships between the parties involved, including other transactions that may be particularly favorable or advantageous to NuStar Energy.
In resolving a conflict, NuStar Energy’s general partner may, unless the resolution is specifically provided for in the partnership agreement, consider:
•the relative interests of the parties involved in the conflict or affected by the action;
•any customary or accepted industry practices or historical dealings with a particular person or entity; and
•generally accepted accounting principles and other factors it considers relevant, if applicable.
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Fiduciary Duties
Fiduciary duties are generally considered to include an obligation to act with due care and loyalty. The duty of care, in the absence of a provision in a partnership agreement providing otherwise, generally requires a general partner to act for the partnership in the same manner as a prudent person would act on his own behalf. The duty of loyalty, in the absence of a provision in a partnership agreement providing otherwise, generally prohibits a general partner from taking any action or engaging in any transaction where a conflict of interest is present. The Delaware law generally provides that a limited partner may institute legal action on a partnership’s behalf to recover damages from a third party where a general partner has refused to institute the action or where an effort to cause a general partner to do so is not likely to succeed. In addition, the statutory or case law of some jurisdictions may permit a limited partner to institute legal action on behalf of himself and all other similarly situated limited partners to recover damages from a general partner for violations of its fiduciary duties to the limited partners.
The Delaware law provides that Delaware limited partnerships may, in their partnership agreements, restrict or expand the fiduciary duties owed by a general partner to limited partners and the partnership.
Fiduciary standards may be modified by NuStar Energy’s partnership agreement. NuStar Energy’s partnership agreement contains various provisions restricting the fiduciary duties that might otherwise be owed by NuStar Energy’s general partner. The following is a summary of the material restrictions of the fiduciary duties owed by NuStar Energy’s general partner to the limited partners:
The partnership agreement contains provisions that waive or consent to conduct by NuStar Energy’s general partner and its affiliates that might otherwise raise issues as to compliance with fiduciary duties or applicable law. For example, the partnership agreement permits NuStar Energy’s general partner to make a number of decisions in its "sole discretion," such as:
•the incurrence of indebtedness;
•the acquisition or disposition of assets, except for the disposition of all of the assets of NuStar Energy, which requires unitholder approval;
•the negotiation of any contracts; and
•the disposition of NuStar Energy’s cash.
Sole discretion entitles NuStar Energy’s general partner to consider only the interests and factors that it desires and it does not have a duty or obligation to give any consideration to any interest of, or factors affecting, NuStar Energy, its affiliates or any limited partner, including the public unitholders. Other provisions of NuStar Energy’s partnership agreement provide that NuStar Energy’s general partner’s actions must be carried out in its reasonable discretion.
The partnership agreement generally provides that affiliated transactions and resolutions of conflicts of interest not involving a required vote of unitholders must be "fair and reasonable" to NuStar Energy under the factors previously set forth. In determining whether a transaction or resolution is "fair and reasonable" NuStar Energy’s general partner may consider interests of all parties involved, including its own. Unless NuStar Energy’s general partner has acted in bad faith, the action taken by NuStar Energy’s general partner will not constitute a breach of its fiduciary duty.
In addition to the other more specific provisions limiting the obligations of NuStar Energy’s general partner, the partnership agreement further provides that NuStar Energy’s general partner and the officers and directors of NuStar GP, LLC will not be liable for monetary damages to NuStar Energy, the limited partners or assignees for errors of judgment or for any acts or omissions if NuStar Energy’s general partner and those other persons acted in good faith.
NuStar Energy is required to indemnify its general partner and NuStar GP, LLC and their officers, directors, employees, affiliates, partners, members, agents and trustees, to the fullest extent permitted by law, against liabilities, costs and expenses incurred by NuStar Energy’s general partner and NuStar GP, LLC or these other persons. This indemnification is required if NuStar Energy’s general partner or these persons acted in good faith and in a manner they reasonably believed to be in, or (in the case of a person other than NuStar Energy’s general partner) not opposed to, the best interests of NuStar Energy. Indemnification is required for criminal proceedings if NuStar Energy’s general partner and NuStar GP, LLC or these other persons had no reasonable cause to believe their conduct was unlawful. Thus, NuStar Energy’s general partner and NuStar GP, LLC could be indemnified for their negligent acts if they met these requirements concerning good faith and the best interests of NuStar Energy.
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DISTRIBUTION STOPPER PURSUANT TO SUBORDINATED NOTES
On January 22, 2013, NuStar Logistics, L.P., a subsidiary of NuStar Energy ("NuStar Logistics"), issued $402.5 million of fixed-to-floating rate subordinated notes due January 15, 2043 (the "Subordinated Notes"). Effective January 15, 2018, the interest rate on the Subordinated Notes switched from a fixed annual rate of 7.625%, payable quarterly in arrears, to an annual rate equal to the sum of the three-month LIBOR for the related quarterly interest period, plus 6.734% payable quarterly, commencing with the interest payment due April 15, 2018. As of December 31, 2021, the interest rate was 6.9%. The Subordinated Notes are fully and unconditionally guaranteed on an unsecured and subordinated basis by NuStar Energy and its subsidiary, NuStar Pipeline Operating Partnership L.P.
In accordance with the terms of the notes, NuStar Logistics may elect to defer interest payments on the Subordinated Notes on one or more occasions for up to five consecutive years. Deferred interest will accumulate at a rate equal to the interest rate then applicable to the Subordinated Notes until paid. If NuStar Logistics elects to defer interest payments, NuStar Energy cannot declare or make cash distributions with respect to, or redeem, purchase or make a liquidation payment with respect to, its equity securities during the period interest is deferred.
15
Exhibit 10.35
RESTRICTED UNIT AWARD AGREEMENT
[U.S.]
This Restricted Unit Award Agreement (“Agreement”), effective as of November 16, 2021 (“Grant Date”), is between NuStar Energy L.P. (the “Partnership”) and the recipient of this Agreement (“Participant”), a participant in the Amended and Restated NuStar Energy L.P. 2019 Long-Term Incentive Plan, as the same may be amended (the “Plan”), pursuant to and subject to the provisions of the Plan. All capitalized terms contained in this Agreement shall have the same definitions as are set forth in the Plan unless otherwise defined herein. The terms governing this Award are set forth below. Certain provisions applicable to this Agreement are set forth on Appendix A.
1.Grant of Restricted Units. The Compensation Committee (the “Committee”) of the Board of Directors of NuStar GP, LLC (the “Company”) hereby grants to Participant the number of Restricted Units under the Plan communicated to the Participant by the Participant’s manager. A “Restricted Unit” is an unfunded, unsecured contractual right (commonly referred to as a “phantom unit”) which, upon vesting, entitles Participant to receive a Unit of the Partnership.
2.Vesting. The Restricted Units granted hereunder are subject to the following Restricted Periods and will vest in the following increments:
| 20% of the Award shall vest on the first anniversary of Grant Date; | ||
| 20% of the Award shall vest on the second anniversary of Grant Date; | ||
| 20% of the Award shall vest on the third anniversary of Grant Date; | ||
| 20% of the Award shall vest on the fourth anniversary of Grant Date; and | ||
| 20% of the Award shall vest on the fifth anniversary of Grant Date. | ||
The Restricted Units may vest prior to the expiration of such period, as set forth in the Plan or herein. Upon the vesting of each Restricted Unit awarded under this Agreement, Participant will be entitled to receive an unrestricted Unit of the Partnership.
3.Distribution Equivalent Rights. Restricted Units are granted hereunder in tandem with 0.575 of a distribution equivalent right (“DERs”) for each Restricted Unit covered by this Award. A DER is a right to receive an amount in cash from the Partnership or its designee equal to the distributions made by the Partnership with respect to a Unit during the period that begins on the Grant Date and ends upon vesting of the tandem Restricted Unit or its forfeiture pursuant to this Agreement or the Plan.
4. Settlement. The issuance of Units under this Award shall be made on or as soon as reasonably practical following the applicable date of vesting or the earlier events set forth in Section 5, but in any event no later than the 60th day following the applicable date of vesting or, if earlier, the events set forth in Section 5. Distributions with respect to DERs will be paid to Participant in cash as soon as reasonably practical following the date distributions are paid with respect to Units during the period such DERs are outstanding, but in all events no later than 60 days following the date related amounts are declared with respect to Units. Upon vesting or forfeiture of a Restricted Unit, the related DER shall automatically and immediately terminate for no consideration, except that unpaid distributions with respect to DERs relating to distributions paid on Units prior to the date of such settlement shall be paid
Page 1
no later than the 60th day following the date such pre-vesting/forfeiture distributions are declared with respect to Units. This Agreement and the Award evidenced hereby are intended to comply with or otherwise be exempt from, and shall be administered consistently in all respects with, Section 409A of the Code and the regulations promulgated thereunder and each payment hereunder shall be considered a separate payment under Section 409A of the Code. If necessary in order to attempt to ensure such compliance, this Agreement may be reformed, to the extent possible, unilaterally by the Partnership consistent with guidance issued by the Internal Revenue Service. Participant agrees that the unrestricted Units to which Participant will be entitled in connection with the vesting of Restricted Units may be issued in uncertificated form and recorded with the Partnership’s or its Affiliates’ service provider.
5. Acceleration Events.
a. Notwithstanding the foregoing, if Participant becomes Disabled (as defined below) while employed by the Company, the Partnership or any of their respective Affiliates or Participant’s employment is terminated because of Participant’s death (such Disability or death, an “Acceleration Event”), then:
i. if the Acceleration Event occurs within one year after the Grant Date (the “Grant Year”), then all then-outstanding Restricted Units and DERs shall automatically be forfeited for no consideration as of the close of business on the date of the Acceleration Event; and
ii. if the Acceleration Event occurs after the last day of the Grant Year (any such later year, a “Post-Grant Year”), then
(A) a portion of the Restricted Units that remain unvested and outstanding on the date of the Acceleration Event shall automatically become vested, where such portion shall be equal to the product of:
(x) the percentage equal to the number of months of the Post-Grant Year elapsed prior to the date of the Acceleration Event; divided by the product of the number of Post-Grant Years remaining, inclusive of the Post-Grant Year in which the Acceleration Event occurs, multiplied by 12 months;
multiplied by:
(y) the number of unvested Restricted Units that would have vested had Participant remained continuously employed with the Company, the Partnership or an Affiliate thereof through the latest date on the vesting schedule in Section 2, and
(B) the remaining Restricted Units (and all DERs) shall automatically and immediately be forfeited for no consideration.
For illustration purposes only: In Year 1, 100 Restricted Units are granted to a participant in November to vest in equal annual installments over a five year period beginning on the first anniversary of the date of grant. In Year 2, the participant dies with a last day of service of June 9. In this scenario, seven months of Year 2 have elapsed, so (x) is 15%, which is multiplied by (y), which is 80. The product of (x) and (y) is twelve, and twelve of the 80 Restricted Units will vest with respect to the participant. The remaining 68 Restricted Units shall automatically be forfeited.
Page 2
| Award Date | Restricted Units Awarded | Restricted Units Vesting | (x) Percent of Restricted Units Vesting | (y) Unvested Restricted Units | Pro-ration Formula | Pro-Rated Vesting | ||||||||||||||||||||||||||
| 2022 | 2023 | 2024 | 2025 | 2026 | ||||||||||||||||||||||||||||
| 11/16/2021 | 100 | 20 | 20 | 20 | 20 | 20 | 7/48 = .15 | 80 | .15 x 80 | 12 | ||||||||||||||||||||||
For purposes of this Agreement, “Disabled” or “Disability” means (i) the inability of Participant to engage in any substantial gainful activity by reason of any medically determinable physical or mental impairment that can be expected to result in death or can be expected to last for a continuous period of not less than twelve (12) months or (ii) the receipt of income replacements by Participant, by reason of any medically determinable physical or mental impairment that can be expected to result in death or can be expected to last for a continuous period of not less than twelve (12) months, for a period of not less than three (3) months under the accident and health plan of the Company, the Partnership or an applicable Affiliate thereof.
b. The Award shall vest in full upon a Change of Control in accordance with Section 6.5(vii) of the Plan.
6. Withholding. The Company, the Partnership or an applicable Affiliate will withhold any taxes due from Participant’s grant as the Company, the Partnership or an applicable Affiliate determines is required by law, which, in the sole discretion of the Committee, may include withholding a number of Restricted Units or the Units issuable thereunder otherwise payable to Participant.
7. Acceptance and Acknowledgement. Participant hereby accepts and agrees to be bound by all of the terms, provisions, conditions and limitations of the Plan and any subsequent amendment or amendments thereto, as if it had been set forth verbatim in this Award. Participant shall be deemed to have timely accepted this Agreement and the terms hereof if Participant has not explicitly rejected this Agreement in writing to the Partnership within sixty (60) days after the Grant Date. Participant hereby acknowledges receipt of a copy of the Plan, this Agreement and Appendix A. Participant has read and understands the terms and provisions thereof, and accepts the Restricted Units and DERs subject to all of the terms and conditions of the Plan and this Agreement. Participant acknowledges that there may be adverse tax consequences upon payment of DERs and/or the vesting or settlement of the Restricted Units or disposition of the underlying Units and that Participant has been advised to consult a tax advisor prior to such vesting, settlement or disposition.
8. Plan and Appendix Incorporated by Reference. The Plan and Appendix A are incorporated into this Agreement by this reference and are made a part hereof for all purposes; provided, however, that, in the event of a conflict between the Plan and this Agreement or between the Plan and Appendix A, the Plan shall control.
9. Restrictions. This Agreement and Participant’s interest in the Restricted Units and the DERs granted by this Agreement are of a personal nature and, except as expressly provided in this Agreement or the Plan, Participant’s rights with respect thereto may not be sold, mortgaged, pledged, assigned, alienated, transferred, conveyed or otherwise disposed of or
Page 3
encumbered in any manner by Participant. Any such attempted sale, mortgage, pledge, assignment, alienation, transfer, conveyance, disposition or encumbrance shall be void, and the Partnership and its Affiliates shall not be bound thereby.
NUSTAR ENERGY L.P.
By: Riverwalk Logistics, L.P., its general partner
By: NuStar GP, LLC, its general partner
By: ___________________________
Bradley C. Barron
President & Chief Executive Officer
Page 4
APPENDIX A
1. No Guarantee of Tax Consequences. None of the Board, the Company, the Partnership or any Affiliate of any of the foregoing makes any commitment or guarantee that any federal, state, local or other tax treatment will (or will not) apply or be available to Participant (or to any person claiming through or on behalf of Participant) or assumes any liability or responsibility with respect to taxes and penalties and interest thereon arising hereunder with respect to Participant (or to any person claiming through or on behalf of Participant).
2. Successors and Assigns. The Partnership and its Affiliates may assign any of their respective rights under this Agreement and it shall be binding and inure to the benefit of such successors and assigns. Subject to the restrictions on transfer set forth herein, this Agreement will be binding upon Participant and Participant’s beneficiaries, executors, administrators and the person(s) to whom the Restricted Units and/or DERs may be transferred by will or the laws of descent or distribution.
3. Governing Law. The validity, construction and effect of this Agreement shall be determined by the laws of the State of Delaware without regard to conflict of laws principles.
4. No Rights as Unitholder. Neither Participant nor any person claiming by, through or under Participant with respect to the Restricted Units or DERs shall have any rights as a unitholder of the Partnership (including, without limitation, voting rights) unless and until the Restricted Units vest and are settled by the issuance of Units.
5. Amendment. The Committee has the right to amend or alter this Agreement, the Restricted Units and/or DERs; provided, that no such amendment shall adversely affect Participant’s material rights under this Agreement without Participant’s consent.
6. No Right to Continued Service. Neither the Plan nor this Agreement shall confer upon Participant any right to be retained in any position, as an Employee, Consultant or Director of the Company, the Partnership or any Affiliate thereof. Further, nothing in the Plan or this Agreement shall be construed to limit the discretion of the Company, the Partnership or any Affiliate thereof to terminate Participant’s service at any time, with or without Cause.
7. Notices. Any notice required to be delivered to the Partnership under this Agreement shall be in writing and addressed to the Secretary of the Company at the Company’s principal offices. Any notice required to be delivered to Participant under this Agreement shall be in writing and addressed to Participant at Participant’s address as then shown in the records of the Company, the Partnership or the applicable Affiliate. Any party hereto may designate another address in writing (or by such other method approved by the Partnership) from time to time.
8. Interpretation. Any dispute regarding the interpretation of this Agreement shall be submitted by such party to the Committee for review. The resolution of such dispute by the Committee shall be final and binding on the parties hereto.
9. Severability. The invalidity or unenforceability of any provision of the Plan or this Agreement shall not affect the validity or enforceability of any other provision of the Plan or this Agreement, and each provision of the Plan and this Agreement shall be severable and enforceable to the extent permitted by law.
Page 5
Exhibit 10.36
NON-EMPLOYEE DIRECTOR
RESTRICTED UNIT AWARD AGREEMENT
This Restricted Unit Award Agreement (“Agreement”), effective as of [GRANT DATE] (“Grant Date”), is between NuStar Energy L.P. (the “Partnership”) and [NAME] (“Participant”), a participant in the Amended and Restated NuStar Energy L.P. 2019 Long-Term Incentive Plan, as the same may be amended (the “Plan”), pursuant to and subject to the provisions of the Plan. All capitalized terms contained in this Agreement shall have the same definitions as are set forth in the Plan unless otherwise defined herein. The terms governing this Award are set forth below. Certain provisions applicable to this Agreement are set forth on Appendix A.
1.Grant of Restricted Units. The Board of Directors (referred to for purposes of this Agreement and the Plan as the “Committee”) of NuStar GP, LLC (the “Company”) hereby grants to Participant [NUMBER OF UNITS] Restricted Units under the Plan. A “Restricted Unit” is an unfunded, unsecured contractual right (commonly referred to as a “phantom unit”) which, upon vesting, entitles Participant to receive a Unit of the Partnership.
2.Vesting. The Restricted Units granted hereunder are subject to the following Restricted Periods and will vest in the following increments:
| 33-1/3% of the Award shall vest on the first anniversary of Grant Date; | ||
| 33-1/3% of the Award shall vest on the second anniversary of Grant Date; and | ||
| 33-1/3% of the Award shall vest on the third anniversary of Grant Date. | ||
The Restricted Units may vest prior to the expiration of such period, as set forth in the Plan or herein. Upon the vesting of each Restricted Unit awarded under this Agreement, Participant will be entitled to receive an unrestricted Unit of the Partnership.
3.Distribution Equivalent Rights. Restricted Units are granted hereunder in tandem with an equal number of distribution equivalent rights (“DERs”). A DER is a right to receive an amount in cash from the Partnership or its designee equal to the distributions made by the Partnership with respect to a Unit during the period that begins on the Grant Date and ends upon vesting of the tandem Restricted Unit or its forfeiture pursuant to this Agreement or the Plan.
4.Settlement. The issuance of Units under this Award shall be made on or as soon as reasonably practical following the applicable date of vesting or the earlier events set forth in Section 5, but in any event no later than the 60th day following the applicable date of vesting or, if earlier, the events set forth in Section 5. Distributions with respect to DERs will be paid to Participant in cash as soon as reasonably practical following the date distributions are paid with respect to Units during the period such DERs are outstanding, but in all events no later than 60 days following the date related amounts are declared with respect to Units. Upon vesting or forfeiture of a Restricted Unit, the related DER shall automatically and immediately terminate for no consideration, except that unpaid distributions with respect to DERs relating to distributions paid on Units prior to the date of such settlement shall be paid no later than the 60th day following the date such pre-vesting/forfeiture distributions are declared with respect to Units. This Agreement and the Award evidenced hereby are intended to comply with or otherwise be exempt from, and shall be administered consistently in all respects with, Section 409A of the Code and the regulations promulgated thereunder
Page 1
and each payment hereunder shall be considered a separate payment under Section 409A of the Code. If necessary in order to attempt to ensure such compliance, this Agreement may be reformed, to the extent possible, unilaterally by the Partnership consistent with guidance issued by the Internal Revenue Service. Participant agrees that the unrestricted Units to which Participant will be entitled in connection with the vesting of Restricted Units may be issued in uncertificated form and recorded with the Partnership’s or its Affiliates’ service provider.
5.Acceleration Events.
a. Notwithstanding the foregoing, if Participant becomes Disabled (as defined below) while providing services to the Company, the Partnership or any of their respective Affiliates or Participant’s service is terminated because of Participant’s death (such Disability or death, an “Acceleration Event”), then:
i. if the Acceleration Event occurs within one year after the Grant Date (the “Grant Year”), then all then-outstanding Restricted Units and DERs shall automatically be forfeited for no consideration as of the close of business on the date of the Acceleration Event; and
ii. if the Acceleration Event occurs after the last day of the Grant Year (any such later year, a “Post-Grant Year”), then
(A) a portion of the Restricted Units that remain unvested and outstanding on the date of the Acceleration Event shall automatically become vested, where such portion shall be equal to the product of:
(x) the percentage equal to the number of months of the Post-Grant Year elapsed prior to the date of the Acceleration Event; divided by the product of the number of Post-Grant Years remaining, inclusive of the Post-Grant Year in which the Acceleration Event occurs, multiplied by 12 months;
multiplied by:
(y) the number of unvested Restricted Units that would have vested had Participant remained continuously providing services to the Company, the Partnership or an Affiliate thereof through the latest date on the vesting schedule in Section 2, and
(B) the remaining Restricted Units (and all DERs) shall automatically and immediately be forfeited for no consideration.
Page 2
For illustration purposes only: In Year 1, 100 Restricted Units are granted to a participant in November to vest in equal annual installments over a three year period beginning on the first anniversary of the date of grant. In Year 2, the participant dies with a last day of service of June 9. In this scenario, seven months of Year 2 have elapsed, so (x) is 29%, which is multiplied by (y), which is 66. The product of (x) and (y) is 19, and 19 of the 66 Restricted Units will vest with respect to the participant. The remaining 47 Restricted Units shall automatically be forfeited.
| Award Date | Restricted Units Awarded | Restricted Units Vesting | (x) Percent of Restricted Units Vesting | (y) Unvested Restricted Units | Pro-ration Formula | Pro-Rated Vesting | ||||||||||||||||||||
| 2022 | 2023 | 2024 | ||||||||||||||||||||||||
| 11/16/2021 | 100 | 34 | 33 | 33 | 7/24= .29 | 66 | .29 x 66 | 19 | ||||||||||||||||||
For purposes of this Agreement, “Disabled” or “Disability” means the inability of Participant to engage in any substantial gainful activity by reason of any medically determinable physical or mental impairment that can be expected to result in death or can be expected to last for a continuous period of not less than twelve (12) months.
b. The Award shall vest in full upon a Change of Control in accordance with Section 6.5(vii) of the Plan.
6.Withholding. The Company, the Partnership or an applicable Affiliate will withhold any taxes due from Participant’s grant as the Company, the Partnership or an applicable Affiliate determines is required by law, which, in the sole discretion of the Committee, may include withholding a number of Restricted Units or the Units issuable thereunder otherwise payable to Participant.
7.Acceptance and Acknowledgement. Participant hereby accepts and agrees to be bound by all of the terms, provisions, conditions and limitations of the Plan and any subsequent amendment or amendments thereto, as if it had been set forth verbatim in this Award. Participant shall be deemed to have timely accepted this Agreement and the terms hereof if Participant has not explicitly rejected this Agreement in writing to the Partnership within sixty (60) days after the Grant Date. Participant hereby acknowledges receipt of a copy of the Plan, this Agreement and Appendix A. Participant has read and understands the terms and provisions thereof, and accepts the Restricted Units and DERs subject to all of the terms and conditions of the Plan and this Agreement. Participant acknowledges that there may be adverse tax consequences upon payment of DERs and/or the vesting or settlement of the Restricted Units or disposition of the underlying Units and that Participant has been advised to consult a tax advisor prior to such vesting, settlement or disposition.
Page 3
8.Plan and Appendix Incorporated by Reference. The Plan and Appendix A are incorporated into this Agreement by this reference and are made a part hereof for all purposes; provided, however, that, in the event of a conflict between the Plan and this Agreement or between the Plan and Appendix A, the Plan shall control.
9.Restrictions. This Agreement and Participant’s interest in the Restricted Units and the DERs granted by this Agreement are of a personal nature and, except as expressly provided in this Agreement or the Plan, Participant’s rights with respect thereto may not be sold, mortgaged, pledged, assigned, alienated, transferred, conveyed or otherwise disposed of or encumbered in any manner by Participant. Any such attempted sale, mortgage, pledge, assignment, alienation, transfer, conveyance, disposition or encumbrance shall be void, and the Partnership and its Affiliates shall not be bound thereby.
NUSTAR ENERGY L.P.
By: Riverwalk Logistics, L.P., its general partner
By: NuStar GP, LLC, its general partner
By: ___________________________
Bradley C. Barron
President & Chief Executive Officer
Page 4
APPENDIX A
1. No Guarantee of Tax Consequences. None of the Board, the Company, the Partnership or any Affiliate of any of the foregoing makes any commitment or guarantee that any federal, state, local or other tax treatment will (or will not) apply or be available to Participant (or to any person claiming through or on behalf of Participant) or assumes any liability or responsibility with respect to taxes and penalties and interest thereon arising hereunder with respect to Participant (or to any person claiming through or on behalf of Participant).
2. Successors and Assigns. The Partnership and its Affiliates may assign any of their respective rights under this Agreement and it shall be binding and inure to the benefit of such successors and assigns. Subject to the restrictions on transfer set forth herein, this Agreement will be binding upon Participant and Participant’s beneficiaries, executors, administrators and the person(s) to whom the Restricted Units and/or DERs may be transferred by will or the laws of descent or distribution.
3. Governing Law. The validity, construction and effect of this Agreement shall be determined by the laws of the State of Delaware without regard to conflict of laws principles.
4. No Rights as Unitholder. Neither Participant nor any person claiming by, through or under Participant with respect to the Restricted Units or DERs shall have any rights as a unitholder of the Partnership (including, without limitation, voting rights) unless and until the Restricted Units vest and are settled by the issuance of Units.
5. Amendment. The Committee has the right to amend or alter this Agreement, the Restricted Units and/or DERs; provided, that no such amendment shall adversely affect Participant’s material rights under this Agreement without Participant’s consent.
6. No Right to Continued Service. Neither the Plan nor this Agreement shall confer upon Participant any right to be retained in any position, as an Employee, Consultant or Director of the Company, the Partnership or any Affiliate thereof. Further, nothing in the Plan or this Agreement shall be construed to limit the discretion of the Company, the Partnership or any Affiliate thereof to terminate Participant’s service at any time, with or without Cause.
7. Notices. Any notice required to be delivered to the Partnership under this Agreement shall be in writing and addressed to the Secretary of the Company at the Company’s principal offices. Any notice required to be delivered to Participant under this Agreement shall be in writing and addressed to Participant at Participant’s address as then shown in the records of the Company, the Partnership or the applicable Affiliate. Any party hereto may designate another address in writing (or by such other method approved by the Partnership) from time to time.
8. Interpretation. Any dispute regarding the interpretation of this Agreement shall be submitted by such party to the Committee for review. The resolution of such dispute by the Committee shall be final and binding on the parties hereto.
9. Severability. The invalidity or unenforceability of any provision of the Plan or this Agreement shall not affect the validity or enforceability of any other provision of the Plan or this Agreement, and each provision of the Plan and this Agreement shall be severable and enforceable to the extent permitted by law.
Page 5
Exhibit 21.01
Subsidiaries of NuStar Energy L.P.
| Name of Entity | Jurisdiction of Organization | ||||
| Cooperatie NuStar Holdings U.A. | Netherlands | ||||
| LegacyStar Services, LLC | Delaware | ||||
| NS Security Services, LLC | Delaware | ||||
| NuStar Energy Services, Inc. | Delaware | ||||
| NuStar Finance LLC | Delaware | ||||
| NuStar GP, Inc. | Delaware | ||||
| NuStar GP, LLC | Delaware | ||||
| NuStar GP Holdings, LLC | Delaware | ||||
| NuStar Holdings B.V. | Netherlands | ||||
| NuStar Internacional, S de R.L. de C.V. | Mexico | ||||
| NuStar Logistics, L.P. | Delaware | ||||
| NuStar Permian Crude Logistics, LLC | Delaware | ||||
| NuStar Permian Holdings, LLC | Delaware | ||||
| NuStar Permian Transportation and Storage, LLC | Delaware | ||||
| NuStar Pipeline Company, LLC | Delaware | ||||
| NuStar Pipeline Holding Company, LLC | Delaware | ||||
| NuStar Pipeline Operating Partnership L.P. | Delaware | ||||
| NuStar Pipeline Partners L.P. | Delaware | ||||
| NuStar Services Company LLC | Delaware | ||||
| NuStar Supply & Trading LLC | Delaware | ||||
| NuStar Terminals Canada Co. | Canada | ||||
| NuStar Terminals Canada Holdings Co. | Canada | ||||
| NuStar Terminals Canada Partnership | Canada | ||||
| NuStar Terminals Corporation N.V. | Curacao | ||||
| NuStar Terminals Delaware, Inc. | Delaware | ||||
| NuStar Terminals International N.V. | Curacao | ||||
| NuStar Terminals Operations Partnership L.P. | Delaware | ||||
| NuStar Terminals Services, Inc. | Delaware | ||||
| Point Tupper Marine Services Co. | Canada | ||||
| Riverwalk Logistics, L.P. | Delaware | ||||
| Shore Terminals LLC | Delaware | ||||
| ST Linden Terminal, LLC | Delaware | ||||
| Star Creek Ranch, LLC | Delaware | ||||
Exhibit 22.01
NuStar Energy L.P.
Subsidiary Guarantors and Issuers of Guaranteed Securities
NuStar Logistics, L.P., a Delaware limited partnership and wholly owned subsidiary of NuStar Energy L.P., a Delaware limited partnership (the “Partnership”), is the issuer of the securities listed in the table below (the “Logistics Notes”). The Logistics Notes are guaranteed by the Partnership and NuStar Pipeline Operating Partnership L.P., a Delaware limited partnership and wholly owned subsidiary of the Partnership.
| Logistics Notes | ||
| 5.750% senior notes due 2025 | ||
| 6.00% senior notes due 2026 | ||
| 5.625% senior notes due 2027 | ||
| 6.375% senior notes due 2030 | ||
| 7.625% fixed-to-floating rate subordinated notes due 2043 | ||
Exhibit 23.01
Consent of Independent Registered Public Accounting Firm
The Board of Directors
NuStar GP, LLC:
We consent to the incorporation by reference in the registration statements on Form S-8 (No. 333-209717, 333-226279, 333-231004, and 333-255637) and on Form S-3 (No. 333-232502 and 333-230823) of our reports dated February 24, 2022, with respect to the consolidated financial statements of NuStar Energy L.P. and the effectiveness of internal control over financial reporting.
/s/ KPMG LLP
San Antonio, Texas
February 24, 2022
Exhibit 31.01
CERTIFICATION PURSUANT TO SECTION 302
OF THE SARBANES-OXLEY ACT OF 2002
I, Bradley C. Barron, certify that:
1. I have reviewed this annual report on Form 10-K of NuStar Energy L.P. (the “registrant”);
2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and
5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):
(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and
(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.
Date: February 24, 2022
| /s/ Bradley C. Barron | ||
| Bradley C. Barron | ||
| President and Chief Executive Officer | ||
Exhibit 31.02
CERTIFICATION PURSUANT TO SECTION 302
OF THE SARBANES-OXLEY ACT OF 2002
I, Thomas R. Shoaf, certify that:
1. I have reviewed this annual report on Form 10-K of NuStar Energy L.P. (the “registrant”);
2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and
5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):
(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and
(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.
Date: February 24, 2022
| /s/ Thomas R. Shoaf | ||
| Thomas R. Shoaf | ||
| Executive Vice President and Chief Financial Officer | ||
Exhibit 32.01
CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350,
AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002
In connection with the Annual Report of NuStar Energy L.P. (the Partnership) on Form 10-K for the year ended December 31, 2021, as filed with the Securities and Exchange Commission on the date hereof (the Report), I, Bradley C. Barron, President and Chief Executive Officer of NuStar GP, LLC, the general partner of the general partner of the Partnership, hereby certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:
1.The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
2.The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Partnership.
| /s/ Bradley C. Barron | ||
| Bradley C. Barron | ||
| President and Chief Executive Officer | ||
| February 24, 2022 | ||
Exhibit 32.02
CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350,
AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002
In connection with the Annual Report of NuStar Energy L.P. (the Partnership) on Form 10-K for the year ended December 31, 2021, as filed with the Securities and Exchange Commission on the date hereof (the Report), I, Thomas R. Shoaf, Executive Vice President and Chief Financial Officer of NuStar GP, LLC, the general partner of the general partner of the Partnership, hereby certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:
1.The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
2.The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Partnership.
| /s/ Thomas R. Shoaf | ||
| Thomas R. Shoaf | ||
| Executive Vice President and Chief Financial Officer | ||
| February 24, 2022 | ||